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Document and Entity Information - USD ($) $ in Millions	12 Months Ended
Document and Entity Information - USD ($) $ in Millions	Dec. 31, 2017	Feb. 26, 2018	Jun. 30, 2017
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	FY
Trading Symbol	CRK
Entity Registrant Name	COMSTOCK RESOURCES INC
Entity Central Index Key	0000023194
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Accelerated Filer
Entity Public Float			$ 99.9
Entity Common Stock, Shares Outstanding		16,166,564

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
ASSETS
Cash and Cash Equivalents	$ 61,255	$ 65,904
Accounts Receivable:
Oil and gas sales	26,700	19,339
Joint interest operations	11,872	3,105
Derivative Financial Instruments	1,318
Assets Held for Sale	198,615
Other Current Assets	2,745	1,824
Total current assets	302,505	90,172
Property and Equipment:
Oil and gas properties, successful efforts method	2,631,750	3,797,101
Other	18,918	19,590
Accumulated depreciation, depletion and amortization	(2,042,739)	(3,018,029)
Net property and equipment	607,929	798,662
Income Taxes Receivable	19,086
Other Assets	899	1,040
Total Assets	930,419	889,874
LIABILITIES AND STOCKHOLDERS' DEFICIT
Accounts Payable	126,034	45,311
Derivative Financial Instruments		6,030
Accrued Expenses	42,455	40,366
Total current liabilities	168,489	91,707
Long-term Debt	1,110,529	1,044,506
Deferred Income Taxes	10,266	9,126
Reserve for Future Abandonment Costs	10,407	15,804
Total liabilities	1,299,691	1,161,143
Commitments and Contingencies
Stockholders' Deficit:
Common stock—$0.50 par, 75,000,000 shares authorized, 13,937,627 and 15,427,561 shares issued and outstanding at December 31, 2016 and 2017, respectively	7,714	6,969
Common stock warrants	3,557	5,672
Additional paid-in capital	546,696	531,924
Accumulated deficit	(927,239)	(815,834)
Total stockholders' deficit	(369,272)	(271,269)
Total liabilities and stockholders' deficit	$ 930,419	$ 889,874

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2017	Dec. 31, 2016
Statement Of Financial Position [Abstract]
Common stock, par value	$ 0.50	$ 0.50
Common stock, shares authorized	75,000,000	75,000,000
Common stock, shares issued	15,427,561	13,937,627
Common stock, shares outstanding	15,427,561	13,937,627

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Statement [Abstract]
Natural gas sales	$ 208,741	$ 122,623	$ 109,753
Oil sales	46,590	53,083	142,669
Total oil and gas sales	255,331	175,706	252,422
Operating expenses:
Production taxes	5,373	4,933	10,286
Gathering and transportation	17,538	15,824	14,298
Lease operating	37,859	47,696	64,502
Exploration		84,144	70,694
Depreciation, depletion and amortization	123,557	141,487	321,323
General and administrative, net	26,137	23,963	23,541
Impairment of oil and gas properties	43,990	27,134	801,347
Loss on sale of oil and gas properties	1,060	14,315	112,085
Total operating expenses	255,514	359,496	1,418,076
Operating loss	(183)	(183,790)	(1,165,654)
Other income (expenses):
Gain (loss) from derivative financial instruments	16,753	(5,356)	2,676
Net gain on extinguishment of debt		189,052	78,741
Interest expense	(146,449)	(128,743)	(118,592)
Other income	530	872	1,275
Total other income (expenses)	(129,166)	55,825	(35,900)
Loss before income taxes	(129,349)	(127,965)	(1,201,554)
Benefit from (provision for) income taxes	17,944	(7,169)	154,445
Net loss	$ (111,405)	$ (135,134)	$ (1,047,109)
Net loss per share – basic and diluted	$ (7.61)	$ (11.52)	$ (113.53)
Basic and diluted weighted average shares outstanding	14,644	11,729	9,223

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' DEFICIT - USD ($) $ in Thousands	Total	Common Stock	Common Stock Warrants	Additional Paid-in Capital	Accumulated Earnings (Deficit)
Beginning Balance at Dec. 31, 2014	$ 870,272	$ 4,686		$ 499,177	$ 366,409
Beginning Balance, Shares at Dec. 31, 2014		9,372,000
Stock-based compensation	8,149	$ 94		8,055
Stock-based compensation, Shares		188,000
Income tax withholdings related to equity awards	(526)	$ (8)		(518)
Income tax withholdings related to equity awards, Shares		(16,000)
Income taxes related to equity award vesting	(2,044)			(2,044)
Net loss	(1,047,109)				(1,047,109)
Ending Balance at Dec. 31, 2015	(171,258)	$ 4,772		504,670	(680,700)
Ending Balance, Shares at Dec. 31, 2015		9,544,000
Stock-based compensation	4,660	$ 116		4,544
Stock-based compensation, Shares		232,000
Income tax withholdings related to equity awards	(313)	$ (20)		(293)
Income tax withholdings related to equity awards, Shares		(41,000)
Common stock issued for debt conversion	1,639	$ 88		1,551
Common stock issued for debt conversion, Shares		176,000
Common stock issued in exchange for debt	13,603	$ 1,385		12,218
Common stock issued in exchange for debt, Shares		2,771,000
Common stock warrants issued	15,623		$ 15,623
Common stock warrants exercised	13	$ 628	(9,951)	9,336
Common stock warrants exercised, Shares		1,256,000
Stock issuance costs	(102)			(102)
Net loss	(135,134)				(135,134)
Ending Balance at Dec. 31, 2016	(271,269)	$ 6,969	5,672	531,924	(815,834)
Ending Balance, Shares at Dec. 31, 2016		13,938,000
Stock-based compensation	5,923	$ 225		5,698
Stock-based compensation, Shares		451,000
Income tax withholdings related to equity awards	(312)	$ (16)		(296)
Income tax withholdings related to equity awards, Shares		(34,000)
Common stock issued for debt conversion	7,789	$ 412		7,377
Common stock issued for debt conversion, Shares		826,000
Common stock warrants exercised	$ 2	$ 124	(2,115)	1,993
Common stock warrants exercised, Shares	1,502,255	247,000
Net loss	$ (111,405)				(111,405)
Ending Balance at Dec. 31, 2017	$ (369,272)	$ 7,714	$ 3,557	$ 546,696	$ (927,239)
Ending Balance, Shares at Dec. 31, 2017		15,428,000

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$ (111,405)	$ (135,134)	$ (1,047,109)
Adjustments to reconcile net loss to net cash provided by (used for) operating activities:
Deferred and non-current income taxes	(18,080)	7,105	(155,249)
Loss on sale of oil and gas properties	1,060	14,315	112,085
Impairment of oil and gas properties	43,990	27,134	801,347
Dry hole costs, exploratory lease impairments and other exploration costs		84,144	70,694
Depreciation, depletion and amortization	123,557	141,487	321,323
(Gain) loss on derivative financial instruments	(16,753)	5,356	(2,676)
Cash settlements of derivative financial instruments	9,405	2,120	1,230
Gain on extinguishment of debt		(189,052)	(78,741)
Amortization of debt discount, premium and issuance costs	35,880	17,788	5,144
Interest paid in-kind	38,073	11,860
Stock-based compensation	5,923	4,660	8,149
Income taxes related to equity award vesting			2,044
Decrease (increase) in accounts receivable	(16,128)	(3,651)	30,248
Decrease (increase) in other current assets	(921)	169	8,112
Increase (decrease) in accounts payable and accrued expenses	80,013	(12,029)	(46,515)
Net cash provided by (used for) operating activities	174,614	(23,728)	30,086
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(180,481)	(57,424)	(264,210)
Proceeds from sales of oil and gas properties	1,528	27,855	102,485
Net cash used for investing activities	(178,953)	(29,569)	(161,725)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings	8,000		790,000
Principal payments on debt	(8,000)		(465,000)
Payments to retire debt		(3,397)	(42,655)
Debt and equity issuance costs		(11,108)	(16,201)
Income tax withholdings related to equity awards	(312)	(313)	(526)
Income taxes related to equity award vesting			(2,044)
Common stock warrants exercised	2	13
Net cash provided by (used for) financing activities	(310)	(14,805)	263,574
Net increase (decrease) in cash and cash equivalents	(4,649)	(68,102)	131,935
Cash and cash equivalents, beginning of the year	65,904	134,006	2,071
Cash and cash equivalents, end of the year	$ 61,255	$ 65,904	$ 134,006

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2017

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

(1) Summary of Significant Accounting Policies

Accounting policies used by Comstock Resources, Inc. and subsidiaries reflect oil and natural gas industry practices and conform to accounting principles generally accepted in the United States of America.

Basis of Presentation and Principles of Consolidation

Comstock Resources, Inc. and its subsidiaries are engaged in oil and natural gas exploration, development and production, and the acquisition of producing oil and natural gas properties. The Company's operations are primarily focused in Texas and Louisiana. The consolidated financial statements include the accounts of Comstock Resources, Inc. and its wholly owned or controlled subsidiaries (collectively, "Comstock" or the "Company"). All significant intercompany accounts and transactions have been eliminated in consolidation. The Company accounts for its undivided interest in oil and gas properties using the proportionate consolidation method, whereby its share of assets, liabilities, revenues and expenses are included in its financial statements. Net loss and comprehensive loss are the same in all periods presented.

On July 29, 2016, the Company effected a one for five (1:5) reverse split of its outstanding shares of common stock. All amounts disclosed in these financial statements have been adjusted to give effect to this reverse stock split in all periods.

Management of the Company has assessed the Company's financial condition, the current capital markets and its future plans given different scenarios of oil and natural gas prices and believes the Company has adequate liquidity to fund its operations for at least twelve months from the date of issuance of these financial statements, which is the requirement to be considered a going concern under generally accepted accounting principles. Management cannot predict how an extended period of low oil and natural gas prices will affect the Company's future operations and liquidity levels.

Use of Estimates in the Preparation of Financial Statements

The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual amounts could differ from those estimates. Changes in the future estimated oil and natural gas reserves or the estimated future cash flows attributable to the reserves that are utilized for impairment analyses could have a significant impact on the future results of operations.

Concentration of Credit Risk and Accounts Receivable

Financial instruments that potentially subject the Company to a concentration of credit risk consist principally of cash and cash equivalents, accounts receivable and derivative financial instruments. The Company places its cash with high credit quality financial institutions and its derivative financial instruments with financial institutions and other firms that management believes have high credit ratings. Substantially all of the Company's accounts receivable are due from either purchasers of oil and gas or participants in oil and gas wells for which the Company serves as the operator. Generally, operators of oil and gas wells have the right to offset future revenues against unpaid charges related to operated wells. Oil and gas sales are generally unsecured. The Company's policy is to assess the collectability of its receivables based upon their age, the credit quality of the purchaser or participant and the potential for revenue offset. The Company has not had any significant credit losses in the past and believes its accounts receivable are fully collectible. Accordingly, no allowance for doubtful accounts has been provided.

Other Current Assets

Other current assets at December 31, 2016 and 2017 consist of the following:


	As of December 31,
	2016		2017
		(In thousands)
Pipe and oil field equipment inventory	$	1,183	$	998
Production tax refunds receivable		303		1,409
Other		338		338
	$	1,824	$	2,745

Fair Value Measurements

Certain accounts within the Company's consolidated balance sheets are required to be measured at fair value on a recurring basis. These include cash equivalents held in bank accounts and derivative financial instruments in the form of oil and natural gas price swap agreements. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. A three-level hierarchy is followed for disclosure to show the extent and level of judgment used to estimate fair value measurements:

Level 1 – Inputs used to measure fair value are unadjusted quoted prices that are available in active markets for the identical assets or liabilities as of the reporting date.

Level 2 – Inputs used to measure fair value, other than quoted prices included in Level 1, are either directly or indirectly observable as of the reporting date through correlation with market data, including quoted prices for similar assets and liabilities in active markets and quoted prices in markets that are not active. Level 2 also includes assets and liabilities that are valued using models or other pricing methodologies that do not require significant judgment since the input assumptions used in the models, such as interest rates and volatility factors, are corroborated by readily observable data from actively quoted markets for substantially the full term of the financial instrument.

Level 3 – Inputs used to measure fair value are unobservable inputs that are supported by little or no market activity and reflect the use of significant management judgment. These values are generally determined using pricing models for which the assumptions utilize management's estimates of market participant assumptions.

The Company's cash and cash equivalents valuation is based on Level 1 measurements. The Company's oil and natural gas price swap agreements were not traded on a public exchange, and their value is determined utilizing a discounted cash flow model based on inputs that are readily available in public markets and, accordingly, the valuation of these swap agreements, is categorized as a Level 2 measurement. There are no financial assets or liabilities accounted for at fair value as of December 31, 2017 that are a Level 3 measurement.

At December 31, 2017, the Company had an asset for the fair value of its natural gas price swap agreements of $1.3 million. The Company had a liability for the fair value of derivative financial instruments outstanding at December 31, 2016 of $6.0 million. There were no offsetting swap positions in 2016 or 2017. The change in fair value of these natural gas swaps was recognized as a gain or loss and included as a component of other income (expense).

As of December 31, 2017, the Company's other financial instruments, comprised solely of its fixed rate debt, had a carrying value of $1.1 billion and a fair value of $1.2 billion. As of December 31, 2016, the Company's fixed rate debt had a carrying value of $1.1 billion and a fair value of $1.1 billion. The fair market value of the Company's fixed rate debt was based on quoted prices as of December 31, 2017 and December 31, 2016, a Level 2 measurement.

Property and Equipment

The Company follows the successful efforts method of accounting for its oil and gas properties. Costs incurred to acquire oil and gas leasehold are capitalized. Acquisition costs for proved oil and gas properties, costs of drilling and equipping productive wells, and costs of unsuccessful development wells are capitalized and amortized on an equivalent unit-of-production basis over the life of the remaining related oil and gas reserves. Equivalent units are determined by converting oil to natural gas at the ratio of one barrel of oil for six thousand cubic feet of natural gas. This conversion ratio is not based on the price of oil or natural gas, and there may be a significant difference in price between an equivalent volume of oil versus natural gas. Amortization is calculated at the field level. The estimated future costs of dismantlement, restoration, plugging and abandonment of oil and gas properties and related facilities disposal are capitalized when asset retirement obligations are incurred and amortized as part of depreciation, depletion and amortization expense. The costs of unproved properties which are determined to be productive are transferred to proved oil and gas properties and amortized on an equivalent unit-of-production basis. Exploratory expenses, including geological and geophysical expenses and delay rentals for unevaluated oil and gas properties, are charged to expense as incurred. Unproved oil and gas properties are periodically assessed for impairment on a property by property basis, and any impairment in value is charged to exploration expense. During 2015 and 2016, impairment charges of $68.9 million and $84.1 million, respectively, were recognized in exploration expense related to certain leases that the Company no longer expects to drill on. Exploratory drilling costs are initially capitalized as unproved property but charged to expense if and when the well is determined not to have found commercial quantities of proved oil and gas reserves. Exploratory drilling costs are evaluated within a one-year period after the completion of drilling.

The Company periodically assesses the need for an impairment of the costs capitalized for its evaluated oil and gas properties on a property-by-property basis. If impairment is indicated based on undiscounted expected future cash flows attributable to the property, then a provision for impairment is recognized to the extent that net capitalized costs exceed the estimated fair value of the property. The Company determines the fair values of its oil and gas properties using a discounted cash flow model and proved and risk-adjusted probable reserves. Undrilled acreage is valued based on sales transactions in comparable areas. Significant Level 3 assumptions associated with the calculation of discounted future cash flows included in the cash flow model include management's outlook for oil and natural gas prices, future oil and natural gas production, production costs, capital expenditures, and the total proved and risk-adjusted probable oil and natural gas reserves expected to be recovered. Management's oil and natural gas price outlook is developed based on third-party longer-term price forecasts as of each measurement date. The expected future net cash flows are discounted using an appropriate discount rate in determining a property's fair value. The oil and natural gas prices used for determining asset impairments will generally differ from those used in the standardized measure of discounted future net cash flows because the standardized measure requires the use of an average price based on the first day of each month of the preceding year.

Comstock sold various oil and gas properties in 2017 for total proceeds of $1.5 million and recognized a loss of $1.1 million on these divestitures. The Company also recognized an impairment of $43.8 million to adjust the carrying value of the Company's South Texas oil properties to fair value less costs to sell of $198.6 million when the assets were designated as held for sale in the fourth quarter of 2017. We determined the fair value based on estimated discounted future net cash flows of the properties appropriately risk adjusted based on indication of values received from potential acquirers in a competitive bid process. There can be no assurance that we will ultimately be able to complete a sale of the properties at the estimated fair value. In 2016, the Company recognized impairments of $27.1 million on certain of its oil and gas properties, including an impairment of $20.8 million to adjust the carrying value of the Company's South Texas natural gas properties to fair value of $42.5 million when the assets were designated as held for sale in the first quarter of 2016. The fair value of the other properties impaired in 2016 was $21.1 million.

In 2015, reductions to management's oil and natural gas price outlook resulted in impairments of $801.3 million of the Company's oil properties in South Texas and Mississippi, and certain of its natural gas properties in Texas and Louisiana. The following table presents the fair value and impairments recorded by the Company in the third quarter and fourth quarter of 2015, as well as the average oil price per barrel and gas price per thousand cubic feet over the life of the properties and the applicable discount rates utilized in the Company's assessments:

	Fair Value		Impairment		Management's Price Outlook		Annual Discount Rate
	Fair Value		Impairment		Oil	Gas	Annual Discount Rate
	(In thousands)				(Per barrel)	(Per Mcf)
Impairments recorded at September 30, 2015:
Oil properties		$330,257		$405,308	$73.70	$4.04	10%-20%
Natural gas properties		$61,625		$139,406	$75.91	$3.91	10%-20%
Impairments recorded at December 31, 2015:
Oil properties		$3,030		$16,036	$73.48		10%-20%
Natural gas properties		$123,926		$238,210	$70.76	$3.74	10%-20%

The Company's estimates of undiscounted future net cash flows attributable to its oil and gas properties may change in the future. The primary factors that may affect estimates of future cash flows include future adjustments, both positive and negative, to proved and appropriate risk-adjusted probable oil and natural gas reserves, results of future drilling activities, future prices for oil and natural gas, and increases or decreases in production and capital costs. As a result of these changes, there may be further impairments in the carrying values of these or other properties.

Other property and equipment consists primarily of gas gathering systems, computer equipment, furniture and fixtures and an airplane which are depreciated over estimated useful lives ranging from three to 31½ years on a straight-line basis.

Other Assets

Other assets primarily consist of deferred costs associated with the Company's bank credit facility. These costs are amortized over the life of the bank credit facility on a straight-line basis which approximates the amortization that would be calculated using an effective interest rate method.

Accrued Expenses

Accrued expenses at December 31, 2016 and 2017 consist of the following:

	As of December 31,
	2016		2017
	(In thousands)
Accrued drilling costs		7,498	$	5,874
Accrued interest payable	$	22,721		21,277
Accrued transportation costs		2,227		3,269
Accrued employee compensation		6,292		6,449
Asset retirement obligation – assets held for sale		—		4,557
Other		1,628		1,029
	$	40,366	$	42,455

Reserve for Future Abandonment Costs

The Company's asset retirement obligations relate to future plugging and abandonment costs of its oil and gas properties and related facilities disposal. The Company records a liability in the period in which an asset retirement obligation is incurred, in an amount equal to the estimated fair value of the obligation that is capitalized. Thereafter, this liability is accreted up to the final retirement cost. Accretion of the discount is included as part of depreciation, depletion and amortization in the accompanying consolidated statements of operations.

The following table summarizes the changes in the Company's total estimated liability:

	2016			2017
	(In thousands)
Reserve for Future Abandonment Costs at beginning of the year	$	20,093		$	15,804
New wells placed on production		3			7
Changes in estimates and timing		(553	)		(1,260	)
Liabilities settled		(409	)		(77	)
Assets held for sale		—			(4,557	)
Asset divestitures		(4,268	)		(320	)
Accretion expense		938			810
Reserve for Future Abandonment Costs at end of the year	$	15,804		$	10,407

Stock-based Compensation

The Company has stock-based employee compensation plans under which stock awards, comprised primarily of restricted stock and performance share units, are issued to employees and non-employee directors. The Company follows the fair value based method in accounting for equity-based compensation. Under the fair value based method, compensation cost is measured at the grant date based on the fair value of the award and is recognized on a straight-line basis over the award vesting period.

Segment Reporting

The Company presently operates in one business segment, the exploration and production of oil and natural gas.

Derivative Financial Instruments and Hedging Activities

The Company accounts for derivative financial instruments (including derivative instruments embedded in other contracts) as either an asset or liability measured at its fair value. Changes in the fair value of derivatives are recognized currently in earnings unless specific hedge accounting criteria are met. The Company estimates fair value based on a discounted cash flow model. The fair value of derivative contracts that expire in less than one year are recognized as current assets or liabilities. Those that expire in more than one year are recognized as long-term assets or liabilities.

Major Purchasers

In 2015, the Company had two major purchasers of its oil and natural gas production that represented 52% and 25% of its total oil and gas sales. In 2016, the Company also had four major purchasers of its oil and natural gas production that represented 42%, 17%, 14% and 12% of its total oil and gas sales. In 2017, the Company had four major purchasers of its oil and natural gas production that accounted for 34%, 17%, 16% and 15% of its total oil and gas sales. The loss of any of these purchasers would not have a material adverse effect on the Company as there is an available market for its oil and natural gas production from other purchasers.

Revenue Recognition and Gas Balancing

Comstock utilizes the sales method of accounting for oil and natural gas revenues whereby revenues are recognized at the time of delivery based on the amount of oil or natural gas sold to purchasers. Revenue is recorded in the month of production based on an estimate of the Company's share of volumes produced and prices realized. The amount of oil or natural gas sold may differ from the amount to which the Company is entitled based on its revenue interests in the properties. The Company did not have any significant imbalance positions at December 31, 2016 or 2017. Sales of oil and natural gas generally occur at the wellhead. When sales of oil and gas occur at locations other than the wellhead, the Company accounts for costs incurred to transport the production to the delivery point as gathering and transportation expenses.

General and Administrative Expenses

General and administrative expenses are reported net of reimbursements of overhead costs that are received from working interest owners of the oil and gas properties operated by the Company of $13.9 million, $12.4 million and $11.7 million in 2015, 2016 and 2017, respectively.

Income Taxes

The Company accounts for income taxes using the asset and liability method, whereby deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of assets and liabilities and their respective tax basis, as well as the tax consequences attributable to the future utilization of existing net operating loss and other carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences and carryforwards are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that the change in rate is enacted.

Earnings Per Share

Unvested share-based payment awards containing nonforfeitable rights to dividends are considered to be participating securities and included in the computation of basic and diluted earnings per share pursuant to the two-class method. Performance share units ("PSUs") represent the right to receive a number of shares of the Company's common stock that may range from zero to up to two times the number of PSUs granted on the award date based on the achievement of certain performance measures during a performance period. The number of potentially dilutive shares related to PSUs is based on the number of shares, if any, which would be issuable at the end of the respective period, assuming that date was the end of the contingency period. The treasury stock method is used to measure the dilutive effect of PSUs. Unexercised common stock warrants represent the right to convert the warrants into common stock at an exercise price of $0.01 per share. The treasury stock method is used to measure the dilutive effect of unexercised common stock warrants. The shares that would be issuable upon exercise of the conversion rights contains in the Company's convertible debt for each period are based on the if-converted method for computing potentially dilutive shares of common stock that could be issued upon conversion. None of the Company's participating securities participate in losses and as such are excluded from the computation of basic earnings per share during periods of net losses.

Basic and diluted earnings per share for the years ended December 31, 2015, 2016 and 2017 were determined as follows:

	2015								2016								2017
	Income (Loss)			Shares		Per Share			Loss			Shares		Per Share			Loss			Shares		Per Share
	(In thousands except per share data)

Basic and Diluted Net Loss Attributable to Common Stock	$	(1,047,109	)		9,223	$	(113.53	)	$	(135,134	)		11,729	$	(11.52	)	$	(111,405	)		14,644	$	(7.61	)

Basic and diluted per share amounts are the same for the years ended December 31, 2015, 2016, and 2017 due to the net loss reported during each of those years.

At December 31, 2015, 2016 and 2017, 314,048, 354,986 and 619,867 shares of unvested restricted stock, respectively, are included in common stock outstanding as such shares have a nonforfeitable right to participate in any dividends that might be declared and have the right to vote. Weighted average shares of unvested restricted stock included in common stock outstanding were as follows:

2015

2016

2017

(In thousands)

Unvested restricted stock

293

344

612

All stock options, unvested PSUs, warrants exercisable into common stock and contingently issuable shares related to the convertible debt that were anti-dilutive to earnings and excluded from weighted average shares used in the computation of earnings per share due to the net loss in each period were as follows:

	2015		2016		2017
	(In thousands except per share data)

Weighted average stock options		20		11		—
Weighted average exercise price per share	$	164.75	$	166.10		—
Weighted average warrants for common stock		—		337		463
Weighted average exercise price per share	$	—	$	0.01	$	0.01
Weighted average PSUs		136		136		274
Weighted average grant date fair value per unit	$	35.35	$	22.17	$	17.12
Weighted average contingently convertible shares		—		11,574		37,046
Weighted average conversion price per share	$	—	$	12.32	$	12.32

Supplementary Information With Respect to the Consolidated Statements of Cash Flows

For the purpose of the consolidated statements of cash flows, the Company considers all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.

Cash payments made for interest and income taxes for the years ended December 31, 2015, 2016 and 2017, respectively, were as follows:

	2015		2016		2017
	(In thousands)
Interest payments	$	94,177	$	105,449	$	73,941
Income tax payments	$	77	$	—	$	3

The Company capitalizes interest on its unevaluated oil and gas property costs during periods when it is conducting exploration activity on this acreage. The Company did not capitalize interest in 2017 or 2016. The Company capitalized interest of $0.9 million in 2015. The Company also paid in-kind $11.9 million and $38.1 million of interest on its convertible notes in 2016 and 2017, respectively.

Recent accounting pronouncements

On January 1, 2017, the Company adopted ASU No. 2016-09, Improvements to Employee Share-Based Payment Accounting ("ASU 2016-09"). The adoption of this new standard did not have a material impact on the Company's financial statements. The Company is accounting for forfeitures in compensation cost as they occur, and it is applying the prospective transition method for presentation of the income tax effects of vested equity awards in its consolidated statements of cash flows.

In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2014-09, Revenue from Contracts with Customers (Topic 606) ("ASU 2014-09"), which supersedes nearly all existing revenue recognition guidance under existing generally accepted accounting principles. This new standard is based upon the principal that revenue is recognized to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. ASU 2014-09 is effective for annual and interim periods beginning after December 15, 2017. The Company has completed its review of its primary oil and natural gas marketing agreements in order to assess the impact of adoption, and it has assessed that adoption of this standard will not have a material impact on the Company's financial statements because revenue will continue to be recognized as production is delivered. The Company is adopting this standard in the first quarter of 2018 utilizing the modified retrospective method.

In February 2016, the FASB issued ASU No. 2016-02, Leases ("ASU 2016-02"). ASU 2016-02 requires lessees to include most leases on their balance sheets, but recognize lease costs in their financial statements in a manner similar to accounting for leases prior to ASC 2016-02. ASU 2016-02 is effective for annual periods ending after December 15, 2018 and interim period thereafter. Early adoption is permitted. The Company is currently evaluating the new guidance and anticipates that certain operating leases that it has in place will be reflected as an asset and a liability in its consolidated balance sheet. The Company has not yet determined which method of adoption it will apply for this new standard.

Acquisitions and Dispositions of Oil and Gas Properties

12 Months Ended

Dec. 31, 2017

Business Combinations [Abstract]

Acquisitions and Dispositions of Oil and Gas Properties

(2) Acquisitions and Dispositions of Oil and Gas Properties

In 2017, the Company entered agreements to jointly develop certain acreage prospective for the Haynesville shale in Louisiana and Texas with USG Properties Haynesville, LLC ("USG"). As of December 31, 2017, USG had acquired approximately 6,300 net acres prospective for Haynesville shale development for the joint development program primarily in Caddo Parish, Louisiana. The Company operates wells drilled on USG's acreage and has the right to acquire a 25% working interest in the acreage by reimbursing USG for the attributable acreage costs of the wells being drilled increasing to 40% starting with the 13^th well drilled. USG is also participating in four wells being drilled in the Company's Bossier shale acreage in Sabine Parish, Louisiana and in a Haynesville shale drilling program on approximately 5,700 acres of Comstock's acreage in Harrison County, Texas. Under the terms of the participation agreements for Sabine Parish and Harrison County acreage owned by the Company, Comstock will receive between $1.1 million and $1.4 million, respectively, for 50% of Comstock's interest for each location for acreage and infrastructure related to each well location, with $400,000 of that amount being paid only if each well meets or exceeds established production targets. Comstock also receives $80,000 for each well drilled as consideration for the Company's services managing the joint development program in addition to customary operating fees for each well drilled except for the four Bossier shale wells. Comstock and USG plan to continue to acquire additional acreage for the joint development program.

Results of operations for the properties that were sold and classified as held for sale in 2015, 2016 and 2017 were as follows:

	Year Ended December 31,
	2015			2016			2017
	(In thousands)
Total oil and gas sales	$	157,956		$	63,303		$	48,949
Total operating expenses⁽¹⁾		(274,651	)		(80,467	)		(44,861	)
Operating income (loss)	$	(116,695	)	$	(17,164	)	$	4,088

(1)	Includes direct operating expenses, depreciation, depletion and amortization and exploration expense. Excludes interest expense, general and administrative expenses and depreciation, depletion and amortization expense subsequent to the date the assets were designated as held for sale.

In October 2017, Comstock adopted a plan of sale for its oil properties located in South Texas. The Company recognized an impairment of $43.8 million in the fourth quarter of 2017 to adjust the carrying value of these assets to their fair value less costs to sell. We determined the fair value based on estimated discounted future net cash flows of the properties appropriately risk adjusted based on indication of values received from potential acquirers in a competitive bid process. There can be no assurance that we will ultimately be able to complete a sale of the properties at the estimated fair value. The asset retirement liability of $4.6 million associated with these assets was reclassified to current liabilities as of December 31, 2017. In December 2016, the Company sold certain of its natural gas properties located in South Texas realizing net proceeds of $25.8 million. The Company recognized a loss on the sale of these assets in 2016 totaling $13.4 million and an impairment of $20.8 million in the first quarter of 2016 to adjust the carrying value of these assets to their fair value. The Company also sold certain other oil and gas properties during 2016 for total proceeds of $2.1 million. The Company recognized a loss of $1.6 million on these divestitures. In July 2015, the Company sold its Burleson County, Texas properties for proceeds of $102.5 million, recognizing a net loss on sale of $112.1 million.

In January 2016, the Company exchanged certain oil and gas properties with another operator in a non-monetary exchange. Under the exchange, the Company received 3,637 net acres in DeSoto Parish, Louisiana, prospective for the Haynesville shale, including four producing wells (3.5 net). The Company exchanged 2,547 net acres in Atascosa County, Texas, including seven producing wells (5.3 net) for the Haynesville shale properties. The Company recognized a gain of $0.7 million on this transaction which was included in the loss on sale of oil and gas properties for the year ended December 31, 2016.

Oil and Gas Producing Activities

12 Months Ended

Dec. 31, 2017

Oil And Gas Exploration And Production Industries Disclosures [Abstract]

Oil and Gas Producing Activities

(3) Oil and Gas Producing Activities

Set forth below is certain information regarding the aggregate capitalized costs of oil and gas properties and costs incurred by the Company for its oil and gas property acquisition, development and exploration activities:

Capitalized Costs

	As of December 31,
	2016			2017
	(In thousands)
Proved properties:
Leasehold costs	$	662,022		$	491,507
Wells and related equipment and facilities		3,135,079			2,140,243
Accumulated depreciation depletion and amortization		(3,009,236	)		(2,032,927	)
	$	787,865		$	598,823

Costs Incurred

	For the Years Ended December 31,
	2015		2016		2017
	(In thousands)
Unproved property acquisitions	$	12,972	$	—	$	—
Development costs		221,265		58,587		177,432
Exploration costs		12,265		—		—
	$	246,502	$	58,587	$	177,432

Long-term Debt

12 Months Ended

Dec. 31, 2017

Debt Disclosure [Abstract]

Long-term Debt

(4) Long-term Debt

Long-term debt is comprised of the following:

	As of December 31,
	2016			2017
	(In thousands)
10% Senior Secured Toggle Notes due 2020:
Principal	$	697,195		$	697,195
Discount, net of amortization		(11,955	)		(8,901	)
7¾% Convertible Second Lien PIK Notes due 2019:
Principal		268,432			284,442
Accrued interest payable in kind		6,645			5,572
Discount, net of amortization		(61,230	)		(38,748	)
9½% Convertible Second Lien PIK Notes due 2020:
Principal		174,182			187,062
Accrued interest payable in kind		735			817
Discount, net of amortization		(38,959	)		(31,844	)
10% Senior Notes due 2020:
Principal		2,805			2,805
7¾% Senior Notes due 2019:
Principal		17,959			17,959
Premium, net of amortization		118			65
9½% Senior Notes due 2020:
Principal		4,860			4,860
Discount, net of amortization		(98	)		(70	)
		0
Debt issuance costs, net of amortization		(16,183	)		(10,685	)
	$	1,044,506		$	1,110,529

The premium and discount on the senior notes are being amortized over the lives of the senior notes using the effective interest rate method. Issuance costs are amortized over the lives of the senior notes on a straight-line basis which approximates the amortization that would be calculated using an effective interest rate method.

The following table summarizes Comstock's principal amount of debt, and any associated paid-in kind interest payable, as of December 31, 2017 by year of maturity:

	2018		2019		2020		2021		2022		Thereafter		Total
	(In thousands)
10% Senior Secured Toggle Notes due 2020	$	—	$	—	$	697,195	$	—	$	—	$	—	$	697,195
7¾% Convertible Second Lien PIK Notes due 2019	$	—	$	290,014	$	—	$	—	$	—	$	—	$	290,014
9½% Convertible Second Lien PIK Notes due 2020		—		—		187,879		—		—		—		187,879
10% Senior Notes due 2020		—		—		2,805		—		—		—		2,805
7¾% Senior Notes due 2019		—		17,959		—		—		—		—		17,959
9½% Senior Notes due 2020		—		—		4,860		—		—		—		4,860
	$	—	$	307,973	$	892,739	$	—	$	—	$	—	$	1,200,712

Interest on the 10% Senior Secured Toggle Notes is payable on March 15 and September 15, and the notes mature on March 15, 2020. The Company has the option to pay up to $75.0 million of accrued interest by issuing additional notes. To the extent that interest is paid in-kind, the interest rate increases to 12¼% only for that interest payment and would result in an additional $91.9 million of notes outstanding.

Interest on the 7¾% Convertible Second Lien PIK Notes is payable on April 1 and October 1, and these notes mature on April 1, 2019. Interest on the 9½% Convertible Second Lien PIK Notes is payable on June 15 and December 15, and these notes mature on June 15, 2020. Interest on the convertible notes is only payable in kind. Each series of the convertible notes is convertible, at the option of the holder, into 81.2 shares of the Company's common stock for each $1,000 of principal amount of notes. The convertible notes will mandatorily convert into 81.2 shares of common stock for each $1,000 of principal amount of the notes following a 15 consecutive trading day period during which the daily volume weighted average price of the Company's common stock is equal to or greater than $12.32 per share.

On September 6, 2016, Comstock completed a debt exchange with the holders of approximately 98% of its then outstanding senior notes. Specifically, the Company issued (i) $697.2 million of new 10% Senior Secured Toggle Notes due 2020 and warrants exercisable for 1,917,342 shares of common stock, in exchange for $697.2 million of the Company's 10% Senior Secured Notes due 2020, (ii) $270.6 million of new 7¾% Convertible Second Lien PIK Notes due 2019 in exchange for $270.6 million of the Company's 7¾% Senior Notes due 2019, and (iii) $169.7 million of new 9½% Convertible Second Lien PIK Notes due 2020 in exchange for $169.7 million of the Company's 9½% Senior Notes due 2020. Accrued and unpaid interest on notes tendered in the exchange was paid in cash. Following the exchange, $2.8 million of the 10% Senior Secured Notes, $18.0 million of the 7¾% Senior Notes and $4.9 million of the 9½% Senior Notes remained outstanding.

The exchange of the 10% Senior Secured Notes due 2020 for the 10% Senior Secured Toggle Notes due 2020 was accounted for as a modification of debt. Accordingly no gain or loss was recognized on the exchange. The value of the warrants issued to the noteholders on September 6, 2016, a Level 2 measurement, is being amortized to interest expense over the life of the notes. Transaction costs of $4.5 million related to the exchange were recognized in 2016 as a reduction to the gain on extinguishment of debt which is reported as a component of other income (loss). The exchange of the 7¾% Senior Notes due 2019 and the 9½% Senior Notes due 2020 for the Convertible Second Lien PIK Notes was accounted for as a debt extinguishment given the substantial difference in the terms of the exchanged notes. A gain of $106.2 million on extinguishment of debt was recognized in 2016 on this exchange representing the difference between the fair market value of the new convertible notes and the carrying amount of the 7¾% Senior Notes due 2019 and the 9½% Senior Notes due 2020 that were exchanged. Transaction costs of $6.5 million related to these exchanges have been reflected as debt issuance costs which are being amortized to interest expense over the lives of the notes. The Company determined the fair value of the convertible notes based upon the average trading prices for the notes subsequent to closing of the exchange. This valuation was a Level 2 measurement.

Prior to the completion of the debt exchange, the Company retired $87.5 million in principal amount of the 7¾% Senior Notes and $19.8 million of the 9½% Senior Notes in 2016 in exchange in the aggregate for the issuance of 2,748,403 shares of common stock and $3.5 million in cash. A gain on extinguishment of debt of $89.6 million was recognized on the retirement of the senior notes during 2016 for the difference between the market value of the stock and the net carrying value of the debt. During 2015, the Company acquired $23.9 million in principal amount of the 7¾% Senior Notes and $105.6 million in principal amount of the 9½% Senior Notes for an aggregate purchase price of $42.7 million. The gain of $82.4 million recognized on the purchase of the senior notes and the loss resulting from the write-off of deferred loan costs associated with the Company's prior bank credit facility of $3.7 million are included in the net gain on extinguishment of debt in 2015.

Comstock has a $50.0 million revolving credit facility with Bank of Montreal and Bank of America, N.A. that matures on March 4, 2019. As of December 31, 2017, there were no borrowings outstanding under the revolving credit facility. Indebtedness under the revolving credit facility is guaranteed by all of the Company's subsidiaries and is secured by substantially all of Comstock's and its subsidiaries' assets. Borrowings under the revolving credit facility bear interest, at Comstock's option, at either (1) LIBOR plus 2.5% or (2) the base rate (which is the higher of the administrative agent's prime rate, the federal funds rate plus 0.5% or 30 day LIBOR plus 1.0%) plus 1.5%. A commitment fee of 0.5% per annum is payable quarterly on the unused credit line. The revolving credit facility contains covenants that, among other things, restrict the payment of cash dividends and repurchases of common stock, limit the amount of additional debt that Comstock may incur and limit the Company's ability to make certain loans, investments and divestitures. The only financial covenants are the maintenance of a ratio of current assets, including availability under the revolving credit facility, to current liabilities of at least 0.9 to 1.0 which increases to 1.0 to 1.0 on March 31, 2018 and the maintenance of an asset coverage ratio of proved developed oil and natural gas reserves to the amount outstanding under the revolving credit facility of at least 2.5 to 1.0. The Company was in compliance with these covenants as of December 31, 2017.

All of the Company's subsidiaries guarantee the bank credit facility, the 10% Senior Secured Toggle Notes, the 7¾% Convertible Second Lien PIK Notes, the 9½% Convertible Second Lien PIK Notes, and the other outstanding senior notes. The bank credit facility, the 10% Senior Secured Toggle Notes and the convertible notes are secured by liens on substantially all of the Company's and its subsidiaries assets. The allocation of proceeds related to the liens on our assets are governed by intercreditor agreements granting priority to the bank credit facility. Proceeds from liens on the convertible notes are also subject to the priority of the 10% Senior Secured Toggle Notes. The liens that previously secured the 10% Senior Secured Notes that were not tendered for exchange were released and these notes are no longer secured.

Commitments and Contingencies

12 Months Ended

Dec. 31, 2017

Commitments And Contingencies Disclosure [Abstract]

Commitments and Contingencies

(5) Commitments and Contingencies

Commitments

The Company rents office space and other facilities under noncancelable operating leases. Rent expense for the years ended December 31, 2015, 2016 and 2017 was $1.5 million, $1.5 million and $1.6 million, respectively. Minimum future payments under the leases at December 31, 2017 are as follows:

	(In thousands)
2018	$	1,560
2019		1,560
2020		1,560
2021		1,560
2022		—
	$	6,240

The Company has entered into natural gas transportation and treating agreements through July 2019. Maximum commitments under these transportation agreements as of December 31, 2017 totaled $2.4 million. As of December 31, 2017, the Company had contracted for contract drilling services through June 2018 of $7.4 million.

Contingencies

From time to time, the Company is involved in certain litigation that arises in the normal course of its operations. The Company records a loss contingency for these matters when it is probable that a liability has been incurred and the amount of the loss can be reasonably estimated. The Company does not believe the resolution of these matters will have a material effect on the Company's financial position, results of operations or cash flows and no material amounts are accrued relative to these matters at December 31, 2016 or 2017.

Stockholders' Equity	12 Months Ended
Stockholders' Equity	Dec. 31, 2017
Equity [Abstract]
Stockholders' Equity	(6) Stockholders' Equity The authorized capital stock of the Company consists of 75 million shares of common stock, $0.50 par value per share, and 5 million shares of preferred stock, $10.00 par value per share. The preferred stock may be issued in one or more series, and the terms and rights of such stock will be determined by the Board of Directors. There were no shares of preferred stock outstanding at December 31, 2016 or 2017. In 2017, holders of the Company's convertible notes converted $9.9 million of principal amount of the notes into 826,327 shares of common stock. In 2016, holders of the Company's convertible notes converted $2.1 million in principal of the notes into 176,175 shares of the Company's common stock. The Company issued warrants to acquire 1,917,342 shares of common stock for $0.01 per share in connection with the 2016 debt exchange. As of December 31, 2017, warrants have been exercised for 1,502,255 shares of common stock, and 415,087 of the warrants remained outstanding.

Stock-based Compensation

12 Months Ended

Dec. 31, 2017

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Stock-based Compensation

(7) Stock-based Compensation

The Company grants restricted shares of common stock and performance share units to key employees and directors as part of their compensation under the 2009 Long-term Incentive Plan. Future awards of performance share units, restricted stock grants or other equity awards are available under the stockholder approved 2009 Long-term Incentive Plan for 1,983,864 shares of common stock.

During 2015, 2016 and 2017, the Company had $8.1 million, $4.7 million and $5.9 million, respectively, in stock-based compensation expense which is included in general and administrative expenses.

Restricted Stock

The fair value of restricted stock grants is amortized over the vesting period, generally one to three years, using the straight-line method. Total compensation expense recognized for restricted stock grants was $6.0 million, $3.4 million and $3.9 million for the years ended December 31, 2015, 2016 and 2017, respectively. The fair value of each restricted share on the date of grant is equal to the market price of a share of the Company's stock.

A summary of restricted stock activity for the year ended December 31, 2017 is presented below:

	Number of Restricted Shares			Weighted Average Grant Price

Outstanding at January 1, 2017		354,986		$15.60
Granted		500,002		$11.11
Vested		(185,652	)	$18.88
Forfeitures		(49,469	)	$13.10
Outstanding at December 31, 2017		619,867		$11.14

The per share weighted average fair value of restricted stock grants in 2015, 2016 and 2017 was $26.70, $5.46 and $11.11, respectively. Total unrecognized compensation cost related to unvested restricted stock of $3.8 million as of December 31, 2017 is expected to be recognized over a period of 1.8 years. The fair value of restricted stock which vested in 2015, 2016 and 2017 was $3.7 million, $1.3 million and $1.7 million, respectively.

Performance Share Units

The Company issues PSUs as part of its long-term equity incentive compensation. PSU awards can result in the issuance of common stock to the holder if certain performance criteria is met during a performance period. The performance periods consist of one year, two years and three years, respectively. The performance criteria for the PSUs are based on the Company's annualized total stockholder return ("TSR") for the performance period as compared with the TSR of certain peer companies for the performance period. The costs associated with PSUs are recognized as general and administrative expense over the performance periods of the awards.

The fair value of PSUs was measured at the grant date using the Geometric Brownian Motion Model ("GBM Model") an equation that can create a series of outcomes over time. The GBM model allows the Company to create multiple prospective total return pathways, statistically analyze these simulations, and ultimately make inferences to the most likely path the total return will take. Significant assumptions used in this simulation include the Company's expected volatility and a risk-free interest rate based on U.S. Treasury yield curve rates with maturities consistent with the vesting periods, as well as the volatilities for each of the Company's peers. Assumptions regarding volatility included the historical volatility of each company's stock and the implied volatilities of publicly traded stock options.

Significant assumptions use to value PSUs in 2015, 2016 and 2017 included:

	For the Years Ended December 31,
	2015		2016		2017

Risk free interest rate		1.1%		0.9%		1.6%
Range of implied volatility:
Minimum		37%		47%		37%
Maximum		65%		92%		134%

In 2015, the Company granted 94,250 PSUs with a grant date fair value of $0.7 million, or $7.30 per unit. In 2016, the Company granted 60,015 PSUs with a grant date fair value of $0.4 million, or $7.00 per unit. In 2017, the Company granted 241,814 PSUs with a grant date fair value of $4.4 million, or $18.17 per unit. The fair value of PSUs is amortized over the vesting period of one to three years, using the straight-line method. Total compensation expense recognized for PSUs was $2.1 million, $1.3 million and $2.0 million for the years ended December 31, 2015, 2016 and 2017, respectively.

A summary of PSU activity for the year ended December 31, 2017 is presented below:

	Number of PSUs		Weighted Average Grant Price

Outstanding at January 1, 2017	134,650		$22.17
Granted	241,814		$18.17
Unearned or forfeited	(94,664	)	$27.01
Outstanding at December 31, 2017	281,800		$17.12

The final number of shares of common stock issued may vary depending upon the performance multiplier, and can result in the issuance of zero to 269,300 shares of common stock based on the achieved performance ranges from zero to two. As of December 31, 2017, there was $3.0 million of total unrecognized expense related to PSUs, which is being amortized through December 31, 2019. 85,987 PSUs were earned in 2018 and 10,857 were forfeited based on completion of a performance period.

Retirement Plan	12 Months Ended
Retirement Plan	Dec. 31, 2017
Compensation And Retirement Disclosure [Abstract]
Retirement Plan	(8) Retirement Plan The Company has a 401(k) profit sharing plan which covers all of its employees. At its discretion, Comstock may match the employees' contributions to the plan. Matching contributions to the plan were $888,000, $758,000 and $760,590 for the years ended December 31, 2015, 2016 and 2017, respectively.

Income Taxes

12 Months Ended

Dec. 31, 2017

Income Tax Disclosure [Abstract]

Income Taxes

(9) Income Taxes

The following is an analysis of the consolidated income tax provision (benefit):

	For the Years Ended December 31,
	2015			2016		2017
	(In thousands)
Current - Federal	$	—		$	—	$	(19,086	)
- State		804			64		136

Deferred - Federal		(149,171	)		—		—
- State		(6,078	)		7,105		1,006
	$	(154,445	)	$	7,169	$	(17,944	)

Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates. The difference between the Company's effective tax rate and the 35% federal statutory rate for 2015 to 2017 and 21% for 2018 and future years is caused by the elimination of the corporate alternative minimum tax pursuant to the Tax Cuts and Jobs Act enacted on December 22, 2017, non-deductible stock compensation, state taxes and the establishment of a valuation allowance on deferred taxes. The impact of these items varies based upon the Company's full year loss and the jurisdictions that are expected to generate the projected losses.

In recording deferred income tax assets, the Company considers whether it is more likely than not that its deferred income tax assets will be realized in the future. The ultimate realization of deferred income tax assets is dependent upon the generation of future taxable income during the periods in which those deferred income tax assets would be deductible. The Company believes that after considering all the available objective evidence, historical and prospective, with greater weight given to historical evidence, management is not able to determine that it is more likely than not that all of its deferred tax assets will be realized. As a result, the Company established valuation allowances for its deferred tax assets and U.S. federal and state net operating loss carryforwards that are not expected to be utilized due to the uncertainty of generating taxable income prior to the expiration of the carryforward periods.

The Company will continue to assess the valuation allowances against deferred tax assets considering all available information obtained in future periods.

The difference between the customary rate of 35% for 2015 to 2017 and the effective tax rate on losses is due to the following:

	For the Years Ended December 31,
	2015			2016			2017
	(In thousands)
Tax benefit at statutory rate	$	(420,544	)	$	(44,788	)	$	(45,272	)
Tax effect of:
Effect of the Tax Cuts and Jobs Act net of valuation allowance		—			—			(19,086	)
Valuation allowance on deferred tax assets		283,585			69,890			41,116
State income taxes, net of federal benefit		(18,218	)		(18,860	)		(892	)
Nondeductible stock-based compensation		539			73			1,408
Net operating loss expirations		—			—			1,548
Other		193			854			3,234
Total	$	(154,445	)	$	7,169		$	(17,944	)

	For the Years Ended December 31,
	2015			2016			2017
Tax at statutory rate		35.0	%		35.0	%		35.0	%
Tax effect of:
Effect of the Tax Cuts and Jobs Act net of valuation allowance		—			—			14.8
Valuation allowance on deferred tax assets		(23.5	)		(54.6	)		(31.8	)
State taxes, net of federal tax benefit		1.4			14.7			0.7
Nondeductible compensation		—			(0.1	)		(1.1	)
Net operating loss expirations		—			—			(1.2	)
Other		—			(0.6	)		(2.5	)
Effective tax rate		12.9	%		(5.6	%)		13.9	%

The tax effects of significant temporary differences representing the net deferred tax liability at December 31, 2016 and 2017 were as follows:

	2016			2017
	(In thousands)
Deferred tax assets:
Property and equipment	$	10,536		$	—
Asset retirement obligation		4,628			3,489
Net operating loss carryforwards		339,914			289,803
Alternative minimum tax carryforward		20,435			1,349
Unrealized hedging loss		2,110			—
Gain on debt exchange and original issue discount		16,169			4,336
Other		8,523			3,782
		402,315			302,759
Valuation allowance on deferred tax assets		(398,120	)		(298,539	)
Deferred tax assets		4,195			4,220

Deferred tax liabilities:
Property and equipment		(9,203	)		(11,878	)
Unrealized hedging income		—			(277	)
Other		(4,118	)		(2,331	)
Deferred tax liabilities		(13,321	)		(14,486	)
Net deferred tax liability	$	(9,126	)	$	(10,266	)

At December 31, 2017, Comstock had the following carryforwards available to reduce future income taxes:

Types of Carryforward	Years of Expiration Carryforward	Amount
		(In thousands)
Net operating loss - U.S. federal	2018-2037	$	923,736
Net operating loss – state taxes	2020-2037	$	1,517,214
Alternative minimum tax credits	Unlimited	$	1,349

At December 31, 2017, the Company had $923.7 million in U.S. federal net operating loss carryforwards and $1.5 billion in certain state net operating loss carryforwards. A valuation allowance has been established against all of the federal loss carryforwards and $1.4 billion of the state loss carryforwards due to the uncertainty of generating future taxable income prior to the expiration of the net operating loss carryforward periods. During 2017 the Company established an additional valuation allowance of $41.1 million for its estimated U.S. federal and state net operating loss carryforwards and other deferred tax assets that are not expected to be utilized due to uncertainty of generating taxable income prior to the expiration of the respective state carry-over periods, and $1.5 million of the Company's federal net operating losses expired.

The Tax Cuts and Jobs Act, which was enacted on December 22, 2017, reduced the corporate income tax rate effective January 1, 2018 from 35% to 21%. Among the other significant tax law changes that potentially affect the Company are the elimination of the corporate alternative minimum tax ("AMT"), changes that require operating losses incurred in 2018 and beyond be carried forward indefinitely with no carryback up to 80% of taxable income in a given year, and limitations on the deduction for interest expense incurred in 2018 or later of up to 70% of its taxable income for the taxable year. The Tax Cuts and Jobs Act preserved deductibility of intangible drilling costs for federal income tax purposes, which allows the Company to deduct a portion of drilling costs in the year incurred and minimizes current taxes payable in periods of taxable income. At December 31, 2017, the Company has not completed its accounting for the tax effects of enactment of the Tax Cuts and Jobs Act; however, it has made reasonable estimates of the effects on its existing deferred tax balances. The Company has remeasured certain deferred federal tax assets and liabilities based on the rates at which they are expected to reverse in the future, which is generally 21%. The provisional amount recognized related to the remeasurement of its deferred federal tax balance was $140.4 million, which was subject to a valuation allowance at December 31, 2017. The Tax Cuts and Jobs Act also repealed the AMT for tax years beginning on or after January 1, 2018 and provides that existing AMT credit carryforwards can be utilized to offset federal taxes for any taxable year. In addition, 50% of any unused AMT credit carryforwards can be refunded during tax years 2018 through 2020. The Company accordingly reversed the valuation allowance on its AMT credit carryforward of $19.1 million that will now be refundable through 2021 and has reclassified this amount from a deferred tax asset to a non-current receivable. The Company is still analyzing certain aspects of the Tax Cuts and Jobs Act, and refining its calculations, which could potentially affect the measurement of those balances or potentially give rise to new deferred tax amounts. Comstock's estimates may also be affected in the future as the Company gains a more thorough understanding of the Tax Cuts and Jobs Act, and how the individual states are implementing this new law.

Future use of the Company's federal and state net operating loss carryforwards may be limited in the event that a cumulative change in the ownership of Comstock's common stock by more than 50% occurs within a three-year period. Such a change in ownership would result in a substantial portion of Comstock's net operating loss carryforwards being eliminated or becoming restricted, and the Company would need to recognize additional valuation allowances reflecting the restricted use of the net operating loss carryforwards in the period when such an ownership change occurred. It is highly likely that a change in ownership that would result from conversion of the Company's convertible notes would result in limits on the future use of its net operating loss carryforwards.

The Company's federal income tax returns for the years subsequent to December 31, 2013 remain subject to examination. The Company's income tax returns in major state income tax jurisdictions remain subject to examination for various periods subsequent to December 31, 2012. The Company currently believes that its significant filing positions are highly certain and that all of its other significant income tax filing positions and deductions would be sustained upon audit or the final resolution would not have a material effect on the consolidated financial statements. Therefore, the Company has not established any significant reserves for uncertain tax positions. Interest and penalties resulting from audits by tax authorities have been immaterial and are included in the provision for income taxes in the consolidated statements of operations.

Derivative Financial Instruments and Hedging Activities

12 Months Ended

Dec. 31, 2017

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Derivative Financial Instruments and Hedging Activities

(10) Derivative Financial Instruments and Hedging Activities

Comstock periodically uses swaps, floors and collars to hedge oil and natural gas prices in order to manage oil and natural gas price risk. Swaps are settled monthly based on differences between the prices specified in the instruments and the settlement prices of futures contracts. Generally, when the applicable settlement price is less than the price specified in the contract, Comstock receives a settlement from the counterparty based on the difference multiplied by the volume or amounts hedged. Similarly, when the applicable settlement price exceeds the price specified in the contract, Comstock pays the counterparty based on the difference. Comstock generally receives a settlement from the counterparty for floors when the applicable settlement price is less than the price specified in the contract, which is based on the difference multiplied by the volumes hedged. For collars, generally Comstock receives a settlement from the counterparty when the settlement price is below the floor and pays a settlement to the counterparty when the settlement price exceeds the cap. No settlement occurs when the settlement price falls between the floor and cap.

All of the Company's derivative financial instruments are used for risk management purposes and by policy none are held for trading or speculative purposes. Comstock minimizes credit risk to counterparties of its derivative financial instruments through formal credit policies, monitoring procedures, and diversification. The Company is not required to provide any credit support to its counterparties other than cross collateralization with the assets securing its bank credit facility. None of the Company's derivative financial instruments involve payment or receipt of premiums.

The Company had the following outstanding derivative financial instruments used for oil and natural gas price risk management:

Commodity and Derivative Type	Weighted-Average Contract Price	Contract Volume (MMBtu)	Contract Period
December 31, 2016:
Natural Gas Swap Agreements	$3.37 per MMBtu	23,400,000	2017
December 31, 2017:
Natural Gas Swap Agreements	$3.38 per MMBtu	2,565,000	2018

None of the derivative contracts were designated as cash flow hedges. The Company recognizes cash settlements and changes in the fair value of its derivative financial instruments as a single component of other income (expenses). Since January 1, 2018 Comstock has added 21,600,000 MMBtu of additional natural gas swap agreements at an average contract price of $3.00 per MMBtu. These contracts begin in March and April 2018 and expire in February and March 2019.

The Company recognized a gain of $2.7 million, a loss of $5.4 million and a gain of $16.8 million from its derivative financial instruments for the years ended December 31, 2015, 2016 and 2017, respectively. Cash settlements received on derivative financial instruments were $1.2 million, $2.1 million and $9.4 million for the years ended December 31, 2015, 2016 and 2017, respectively. The estimated fair value and carrying value of the Company's derivative financial instruments, was a current liability of $6.0 million as of December 31, 2016 and was a current asset of $1.3 million as of December 31, 2017.

Supplementary Quarterly Financial Data (Unaudited)

12 Months Ended

Dec. 31, 2017

Quarterly Financial Information Disclosure [Abstract]

Supplementary Quarterly Financial Data (Unaudited)

(11) Supplementary Quarterly Financial Data (Unaudited)

	2016
	First			Second			Third			Fourth			Total
	(In thousands, except per share data)
Total oil and gas sales	$	36,163		$	40,715		$	50,330		$	48,498		$	175,706
Operating loss	$	(56,490	)	$	(22,706	)	$	(98,789	)	$	(5,805	)	$	(183,790	)
Net income (loss)	$	(56,577	)	$	4,852		$	(28,476	)	$	(54,933	)	$	(135,134	)
Income (loss) per share:
Basic and diluted	$	(5.71	)	$	0.42		$	(2.32	)	$	(4.48	)	$	(11.52	)

	2017
	First			Second			Third			Fourth			Total
	(In thousands, except per share data)
Total oil and gas sales	$	53,801		$	61,471		$	66,811		$	73,248		$	255,331
Operating income (loss)	$	2,381		$	10,470		$	11,190		$	(24,224	)	$	(183	)
Net loss	$	(22,931	)	$	(21,442	)	$	(24,736	)	$	(42,296	)	$	(111,405	)
Loss per share:
Basic and diluted	$	(1.61	)	$	(1.45	)	$	(1.67	)	$	(2.86	)	$	(7.61	)

Basic and diluted per share amounts are the same for each of the quarters and for the years ended where a net loss was reported.

Results of operations include the following non-routine items of income (expense), which are presented before the effect of income taxes:


	2016
	First			Second			Third			Fourth			Total
	(In thousands)
Gain (loss) on sale of oil and gas properties	$	740		$	(1,647	)	$	(13,196	)	$	(212	)	$	(14,315	)
Net gain (loss) on extinguishment of debt	$	33,380		$	56,196		$	100,540		$	(1,064	)	$	189,052
Impairments of unproved oil and gas properties	$	(7,753	)	$	—		$	(76,391	)	$	—		$	(84,144	)
Impairments of proved oil and gas properties	$	(22,718	)	$	(1,742	)	$	(113	)	$	(2,561	)	$	(27,134	)


	2017
	First			Second		Third			Fourth			Total
	(In thousands)
Gain (loss) on sale of oil and gas properties	$	(24	)	$	—	$	(1,036	)	$	—		$	(1,060	)
Impairments of proved oil and gas properties	$	—		$	—	$	—		$	(43,990	)	$	(43,990	)

Oil and Gas Reserves Information (Unaudited)

12 Months Ended

Dec. 31, 2017

Extractive Industries [Abstract]

Oil and Gas Reserves Information (Unaudited)

(12) Oil and Gas Reserves Information (Unaudited)

Set forth below is a summary of the changes in Comstock's net quantities of oil and natural gas reserves for each of the three years in the period ended December 31, 2017:

	2015						2016						2017
	Oil (MBbls)			Natural Gas (MMcf)			Oil (MBbls)			Natural Gas (MMcf)			Oil (MBbls)			Natural Gas (MMcf)
Proved Reserves:
Beginning of year		20,854			495,266			9,229			569,596			7,277			872,468
Revisions of previous estimates		(5,096	)		(41,437	)		(406	)		130,416			1,232			33,721
Extensions and discoveries		231			168,539			64			285,076			1			291,881
Sales of minerals in place		(3,671	)		(5,096	)		(222	)		(58,942	)		(7	)		(7,593	)
Production		(3,089	)		(47,676	)		(1,388	)		(53,678	)		(951	)		(73,521	)
End of year		9,229			569,596			7,277			872,468			7,552			1,116,956
Proved Developed Reserves:
Beginning of year		16,247			324,598			9,229			311,130			7,277			321,527
End of year		9,229			311,130			7,277			321,527			7,552			436,114
Proved Undeveloped Reserves:
Beginning of year		4,607			170,668			—			258,466			—			550,941
End of year		—			258,466			—			550,941			—			680,842

Reserves associated with Assets Held for Sale:
Proved Reserves
Beginning of year		16,282			14,716			8,701			9,119			6,950			9,915
End of year		8,701			9,119			6,950			9,915			7,116			10,484
Proved Developed Reserves
Beginning of year		14,028			14,071			8,701			9,119			6,950			9,915
End of year		8,701			9,119			6,950			9,915			7,116			10,484
Proved Undeveloped Reserves
Beginning of year		2,253			645			—			—			—			—
End of year		—			—			—			—			—			—

The upward revisions to previous estimates in 2016 were primarily performance-related and were attributable to the Company's well performance in the Haynesville shale as well as the expansion of the Company's future drilling plans. The revisions in 2015 and 2017 were primarily related to changes in oil and natural gas prices.

The proved oil and gas reserves utilized in the preparation of the financial statements were estimated by Lee Keeling and Associates, independent petroleum consultants, in accordance with guidelines established by the Securities and Exchange Commission and the Financial Accounting Standards Board, which require that reserve reports be prepared under existing economic and operating conditions with no provision for price and cost escalation except by contractual agreement. All of the Company's reserves are located onshore in the continental United States of America.

The following table sets forth the standardized measure of discounted future net cash flows relating to proved reserves at December 31, 2016 and 2017:

	2016			2017
	(In thousands)
Cash Flows Relating to Proved Reserves:
Future Cash Flows	$	2,267,877		$	3,588,764
Future Costs:
Production		(798,454	)		(986,398	)
Development and Abandonment		(502,848	)		(672,559	)
Future Income Taxes		(6,488	)		5,239
Future Net Cash Flows		960,087			1,935,046
10% Discount Factor		(530,812	)		(1,053,502	)
Standardized Measure of Discounted Future Net Cash Flows	$	429,275		$	881,544
Standardized Measure of Discounted Future Net Cash Flows Related to Assets Held for Sale	$	77,146		$	109,134

The standardized measure of discounted future net cash flows at the end of 2016 and 2017 was determined based on the simple average of the first of month market prices for oil and natural gas for each year. Prices were $37.62 per barrel of oil and $ 2.29 per Mcf of natural gas for 2016 and $48.71 per barrel of oil and $ 2.88 per Mcf of natural gas for 2017. Prices used in determining quantities of oil and natural gas reserves and future cash inflows from oil and natural gas reserves represent prices received at the Company's sales point. These prices have been adjusted from posted or index prices for both location and quality differences. Future development and production costs are computed by estimating the expenditures to be incurred in developing and producing proved oil and gas reserves at the end of the year, based on year end costs and assuming continuation of existing economic conditions. Future income tax expenses are computed by applying the appropriate statutory tax rates to the future pre-tax net cash flows relating to proved reserves, net of the tax basis of the properties involved. The future income tax expenses give effect to permanent differences and tax credits, but do not reflect the impact of future operations.

The following table sets forth the changes in the standardized measure of discounted future net cash flows relating to proved reserves for the years ended December 31, 2015, 2016 and 2017:

	2015			2016			2017
	(In thousands)
Standardized Measure, Beginning of Year	$	1,090,660		$	372,139		$	429,275
Net change in sales price, net of production costs		(751,774	)		(45,379	)		326,662
Development costs incurred during the year which were previously estimated		157,390			45,648			119,864
Revisions of quantity estimates		(111,454	)		113,583			57,042
Accretion of discount		114,427			37,251			43,130
Changes in future development and abandonment costs		14,901			5,315			(62,509	)
Changes in timing and other		(44,439	)		(38,071	)		(15,565	)
Extensions and discoveries		56,216			70,149			167,135
Sales of minerals in place		(43,694	)		(22,449	)		(6,027	)
Sales, net of production costs		(163,336	)		(107,253	)		(194,562	)
Net changes in income taxes		53,242			(1,658	)		17,099
Standardized Measure, End of Year	$	372,139		$	429,275		$	881,544

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2017

Accounting Policies [Abstract]

Basis of Presentation and Principles of Consolidation

Use of Estimates in the Preparation of Financial Statements

Concentration Of Credit Risk And Accounts Receivable

Concentration of Credit Risk and Accounts Receivable

Other Current Assets

Other current assets at December 31, 2016 and 2017 consist of the following:


	As of December 31,
	2016		2017
		(In thousands)
Pipe and oil field equipment inventory	$	1,183	$	998
Production tax refunds receivable		303		1,409
Other		338		338
	$	1,824	$	2,745

Fair Value Measurements

Level 1 – Inputs used to measure fair value are unadjusted quoted prices that are available in active markets for the identical assets or liabilities as of the reporting date.

Property and Equipment

	Fair Value		Impairment		Management's Price Outlook		Annual Discount Rate
	Fair Value		Impairment		Oil	Gas	Annual Discount Rate
	(In thousands)				(Per barrel)	(Per Mcf)
Impairments recorded at September 30, 2015:
Oil properties		$330,257		$405,308	$73.70	$4.04	10%-20%
Natural gas properties		$61,625		$139,406	$75.91	$3.91	10%-20%
Impairments recorded at December 31, 2015:
Oil properties		$3,030		$16,036	$73.48		10%-20%
Natural gas properties		$123,926		$238,210	$70.76	$3.74	10%-20%

Other Assets

Accrued Expenses

Accrued expenses at December 31, 2016 and 2017 consist of the following:

	As of December 31,
	2016		2017
	(In thousands)
Accrued drilling costs		7,498	$	5,874
Accrued interest payable	$	22,721		21,277
Accrued transportation costs		2,227		3,269
Accrued employee compensation		6,292		6,449
Asset retirement obligation – assets held for sale		—		4,557
Other		1,628		1,029
	$	40,366	$	42,455

Reserve for Future Abandonment Costs

The following table summarizes the changes in the Company's total estimated liability:

	2016			2017
	(In thousands)
Reserve for Future Abandonment Costs at beginning of the year	$	20,093		$	15,804
New wells placed on production		3			7
Changes in estimates and timing		(553	)		(1,260	)
Liabilities settled		(409	)		(77	)
Assets held for sale		—			(4,557	)
Asset divestitures		(4,268	)		(320	)
Accretion expense		938			810
Reserve for Future Abandonment Costs at end of the year	$	15,804		$	10,407

Stock-Based Compensation

Stock-based Compensation

Segment Reporting

The Company presently operates in one business segment, the exploration and production of oil and natural gas.

Derivative Financial Instruments and Hedging Activities

Major Purchasers

Revenue Recognition and Gas Balancing

General and Administrative Expenses

Income Taxes

Earnings Per Share

Basic and diluted earnings per share for the years ended December 31, 2015, 2016 and 2017 were determined as follows:

	2015								2016								2017
	Income (Loss)			Shares		Per Share			Loss			Shares		Per Share			Loss			Shares		Per Share
	(In thousands except per share data)

Basic and Diluted Net Loss Attributable to Common Stock	$	(1,047,109	)		9,223	$	(113.53	)	$	(135,134	)		11,729	$	(11.52	)	$	(111,405	)		14,644	$	(7.61	)

Basic and diluted per share amounts are the same for the years ended December 31, 2015, 2016, and 2017 due to the net loss reported during each of those years.

2015

2016

2017

(In thousands)

Unvested restricted stock

293

344

612

	2015		2016		2017
	(In thousands except per share data)

Weighted average stock options		20		11		—
Weighted average exercise price per share	$	164.75	$	166.10		—
Weighted average warrants for common stock		—		337		463
Weighted average exercise price per share	$	—	$	0.01	$	0.01
Weighted average PSUs		136		136		274
Weighted average grant date fair value per unit	$	35.35	$	22.17	$	17.12
Weighted average contingently convertible shares		—		11,574		37,046
Weighted average conversion price per share	$	—	$	12.32	$	12.32

Supplementary Information With Respect to the Consolidated Statements of Cash Flows

For the purpose of the consolidated statements of cash flows, the Company considers all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.

Cash payments made for interest and income taxes for the years ended December 31, 2015, 2016 and 2017, respectively, were as follows:

	2015		2016		2017
	(In thousands)
Interest payments	$	94,177	$	105,449	$	73,941
Income tax payments	$	77	$	—	$	3

Recent Accounting Pronouncements

Recent accounting pronouncements

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2017

Accounting Policies [Abstract]

Summary of Other Current Assets

Other current assets at December 31, 2016 and 2017 consist of the following:


	As of December 31,
	2016		2017
		(In thousands)
Pipe and oil field equipment inventory	$	1,183	$	998
Production tax refunds receivable		303		1,409
Other		338		338
	$	1,824	$	2,745

Schedule of Fair Value Impairments, Average Prices of Oil and Gas Properties And Applicable Discount Rates

The following table presents the fair value and impairments recorded by the Company in the third quarter and fourth quarter of 2015, as well as the average oil price per barrel and gas price per thousand cubic feet over the life of the properties and the applicable discount rates utilized in the Company's assessments:

	Fair Value		Impairment		Management's Price Outlook		Annual Discount Rate
	Fair Value		Impairment		Oil	Gas	Annual Discount Rate
	(In thousands)				(Per barrel)	(Per Mcf)
Impairments recorded at September 30, 2015:
Oil properties		$330,257		$405,308	$73.70	$4.04	10%-20%
Natural gas properties		$61,625		$139,406	$75.91	$3.91	10%-20%
Impairments recorded at December 31, 2015:
Oil properties		$3,030		$16,036	$73.48		10%-20%
Natural gas properties		$123,926		$238,210	$70.76	$3.74	10%-20%

Summary of Accrued Expenses

Accrued expenses at December 31, 2016 and 2017 consist of the following:

	As of December 31,
	2016		2017
	(In thousands)
Accrued drilling costs		7,498	$	5,874
Accrued interest payable	$	22,721		21,277
Accrued transportation costs		2,227		3,269
Accrued employee compensation		6,292		6,449
Asset retirement obligation – assets held for sale		—		4,557
Other		1,628		1,029
	$	40,366	$	42,455

Summary of Changes in Reserve for Future Abandonment Costs

The following table summarizes the changes in the Company's total estimated liability:

	2016			2017
	(In thousands)
Reserve for Future Abandonment Costs at beginning of the year	$	20,093		$	15,804
New wells placed on production		3			7
Changes in estimates and timing		(553	)		(1,260	)
Liabilities settled		(409	)		(77	)
Assets held for sale		—			(4,557	)
Asset divestitures		(4,268	)		(320	)
Accretion expense		938			810
Reserve for Future Abandonment Costs at end of the year	$	15,804		$	10,407

Basic and Diluted Earnings Per Share

Basic and diluted earnings per share for the years ended December 31, 2015, 2016 and 2017 were determined as follows:

	2015								2016								2017
	Income (Loss)			Shares		Per Share			Loss			Shares		Per Share			Loss			Shares		Per Share
	(In thousands except per share data)

Basic and Diluted Net Loss Attributable to Common Stock	$	(1,047,109	)		9,223	$	(113.53	)	$	(135,134	)		11,729	$	(11.52	)	$	(111,405	)		14,644	$	(7.61	)

Weighted Average Shares of Unvested Restricted Stock

Weighted average shares of unvested restricted stock included in common stock outstanding were as follows:

2015

2016

2017

(In thousands)

Unvested restricted stock

293

344

612

Common Stock Stock Options and Convertible Stock Anti-Dilutive to Earnings Excluded from Weighted Average Shares Used in Computation of Earning Per Share

	2015		2016		2017
	(In thousands except per share data)

Weighted average stock options		20		11		—
Weighted average exercise price per share	$	164.75	$	166.10		—
Weighted average warrants for common stock		—		337		463
Weighted average exercise price per share	$	—	$	0.01	$	0.01
Weighted average PSUs		136		136		274
Weighted average grant date fair value per unit	$	35.35	$	22.17	$	17.12
Weighted average contingently convertible shares		—		11,574		37,046
Weighted average conversion price per share	$	—	$	12.32	$	12.32

Cash Payments Made for Interest and Income Taxes

Cash payments made for interest and income taxes for the years ended December 31, 2015, 2016 and 2017, respectively, were as follows:

	2015		2016		2017
	(In thousands)
Interest payments	$	94,177	$	105,449	$	73,941
Income tax payments	$	77	$	—	$	3

Acquisitions and Dispositions of Oil and Gas Properties (Tables)

12 Months Ended

Dec. 31, 2017

Business Combinations [Abstract]

Results of Operations for Properties

Results of operations for the properties that were sold and classified as held for sale in 2015, 2016 and 2017 were as follows:

	Year Ended December 31,
	2015			2016			2017
	(In thousands)
Total oil and gas sales	$	157,956		$	63,303		$	48,949
Total operating expenses⁽¹⁾		(274,651	)		(80,467	)		(44,861	)
Operating income (loss)	$	(116,695	)	$	(17,164	)	$	4,088

(1)	Includes direct operating expenses, depreciation, depletion and amortization and exploration expense. Excludes interest expense, general and administrative expenses and depreciation, depletion and amortization expense subsequent to the date the assets were designated as held for sale.

Oil and Gas Producing Activities (Tables)

12 Months Ended

Dec. 31, 2017

Oil And Gas Exploration And Production Industries Disclosures [Abstract]

Capitalized Costs Related to Oil and Gas Property Acquisition Exploration and Development Activities

Capitalized Costs

	As of December 31,
	2016			2017
	(In thousands)
Proved properties:
Leasehold costs	$	662,022		$	491,507
Wells and related equipment and facilities		3,135,079			2,140,243
Accumulated depreciation depletion and amortization		(3,009,236	)		(2,032,927	)
	$	787,865		$	598,823

Costs Incurred Related to Oil and Gas Property Acquisition Exploration and Development Activities

Costs Incurred

	For the Years Ended December 31,
	2015		2016		2017
	(In thousands)
Unproved property acquisitions	$	12,972	$	—	$	—
Development costs		221,265		58,587		177,432
Exploration costs		12,265		—		—
	$	246,502	$	58,587	$	177,432

Long-term Debt (Tables)

12 Months Ended

Dec. 31, 2017

Debt Disclosure [Abstract]

Long-term Debt

Long-term debt is comprised of the following:

	As of December 31,
	2016			2017
	(In thousands)
10% Senior Secured Toggle Notes due 2020:
Principal	$	697,195		$	697,195
Discount, net of amortization		(11,955	)		(8,901	)
7¾% Convertible Second Lien PIK Notes due 2019:
Principal		268,432			284,442
Accrued interest payable in kind		6,645			5,572
Discount, net of amortization		(61,230	)		(38,748	)
9½% Convertible Second Lien PIK Notes due 2020:
Principal		174,182			187,062
Accrued interest payable in kind		735			817
Discount, net of amortization		(38,959	)		(31,844	)
10% Senior Notes due 2020:
Principal		2,805			2,805
7¾% Senior Notes due 2019:
Principal		17,959			17,959
Premium, net of amortization		118			65
9½% Senior Notes due 2020:
Principal		4,860			4,860
Discount, net of amortization		(98	)		(70	)
		0
Debt issuance costs, net of amortization		(16,183	)		(10,685	)
	$	1,044,506		$	1,110,529

Principal Amount of Debt and Associated Paid-in Kind Interest Payable by Year of Maturity

The following table summarizes Comstock's principal amount of debt, and any associated paid-in kind interest payable, as of December 31, 2017 by year of maturity:

	2018		2019		2020		2021		2022		Thereafter		Total
	(In thousands)
10% Senior Secured Toggle Notes due 2020	$	—	$	—	$	697,195	$	—	$	—	$	—	$	697,195
7¾% Convertible Second Lien PIK Notes due 2019	$	—	$	290,014	$	—	$	—	$	—	$	—	$	290,014
9½% Convertible Second Lien PIK Notes due 2020		—		—		187,879		—		—		—		187,879
10% Senior Notes due 2020		—		—		2,805		—		—		—		2,805
7¾% Senior Notes due 2019		—		17,959		—		—		—		—		17,959
9½% Senior Notes due 2020		—		—		4,860		—		—		—		4,860
	$	—	$	307,973	$	892,739	$	—	$	—	$	—	$	1,200,712

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=84159872&loc=d3e21475-112644

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=75038535&loc=d3e64711-112823

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=64930739&loc=d3e28878-108400

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=84159872&loc=d3e21538-112644

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=84159872&loc=d3e21506-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=64930785&loc=d3e28541-108399

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=64930785&loc=d3e28551-108399

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=84159872&loc=d3e21521-112644

+ Details

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2017

Commitments And Contingencies Disclosure [Abstract]

Minimum Future Payments under Leases

	(In thousands)
2018	$	1,560
2019		1,560
2020		1,560
2021		1,560
2022		—
	$	6,240

Stock-based Compensation (Tables)

12 Months Ended

Dec. 31, 2017

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Summary of Restricted Stock Activity

A summary of restricted stock activity for the year ended December 31, 2017 is presented below:

	Number of Restricted Shares			Weighted Average Grant Price

Outstanding at January 1, 2017		354,986		$15.60
Granted		500,002		$11.11
Vested		(185,652	)	$18.88
Forfeitures		(49,469	)	$13.10
Outstanding at December 31, 2017		619,867		$11.14

Summary of Significant Assumptions Use to Value PSUs

Significant assumptions use to value PSUs in 2015, 2016 and 2017 included:

	For the Years Ended December 31,
	2015		2016		2017

Risk free interest rate		1.1%		0.9%		1.6%
Range of implied volatility:
Minimum		37%		47%		37%
Maximum		65%		92%		134%

Summary of PSU Activity

A summary of PSU activity for the year ended December 31, 2017 is presented below:

	Number of PSUs		Weighted Average Grant Price

Outstanding at January 1, 2017	134,650		$22.17
Granted	241,814		$18.17
Unearned or forfeited	(94,664	)	$27.01
Outstanding at December 31, 2017	281,800		$17.12

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2017

Income Tax Disclosure [Abstract]

Income Tax Provision (Benefit)

The following is an analysis of the consolidated income tax provision (benefit):

	For the Years Ended December 31,
	2015			2016		2017
	(In thousands)
Current - Federal	$	—		$	—	$	(19,086	)
- State		804			64		136

Deferred - Federal		(149,171	)		—		—
- State		(6,078	)		7,105		1,006
	$	(154,445	)	$	7,169	$	(17,944	)

Income Tax Expense Benefit Income Tax Reconciliation

The difference between the customary rate of 35% for 2015 to 2017 and the effective tax rate on losses is due to the following:

	For the Years Ended December 31,
	2015			2016			2017
	(In thousands)
Tax benefit at statutory rate	$	(420,544	)	$	(44,788	)	$	(45,272	)
Tax effect of:
Effect of the Tax Cuts and Jobs Act net of valuation allowance		—			—			(19,086	)
Valuation allowance on deferred tax assets		283,585			69,890			41,116
State income taxes, net of federal benefit		(18,218	)		(18,860	)		(892	)
Nondeductible stock-based compensation		539			73			1,408
Net operating loss expirations		—			—			1,548
Other		193			854			3,234
Total	$	(154,445	)	$	7,169		$	(17,944	)

Difference Between Customary Rate and Effective Tax Rate on Income Before Income Taxes Due

	For the Years Ended December 31,
	2015			2016			2017
Tax at statutory rate		35.0	%		35.0	%		35.0	%
Tax effect of:
Effect of the Tax Cuts and Jobs Act net of valuation allowance		—			—			14.8
Valuation allowance on deferred tax assets		(23.5	)		(54.6	)		(31.8	)
State taxes, net of federal tax benefit		1.4			14.7			0.7
Nondeductible compensation		—			(0.1	)		(1.1	)
Net operating loss expirations		—			—			(1.2	)
Other		—			(0.6	)		(2.5	)
Effective tax rate		12.9	%		(5.6	%)		13.9	%

Tax Effects of Significant Temporary Differences Representing Net Deferred Tax Asset and Liability

The tax effects of significant temporary differences representing the net deferred tax liability at December 31, 2016 and 2017 were as follows:

	2016			2017
	(In thousands)
Deferred tax assets:
Property and equipment	$	10,536		$	—
Asset retirement obligation		4,628			3,489
Net operating loss carryforwards		339,914			289,803
Alternative minimum tax carryforward		20,435			1,349
Unrealized hedging loss		2,110			—
Gain on debt exchange and original issue discount		16,169			4,336
Other		8,523			3,782
		402,315			302,759
Valuation allowance on deferred tax assets		(398,120	)		(298,539	)
Deferred tax assets		4,195			4,220

Deferred tax liabilities:
Property and equipment		(9,203	)		(11,878	)
Unrealized hedging income		—			(277	)
Other		(4,118	)		(2,331	)
Deferred tax liabilities		(13,321	)		(14,486	)
Net deferred tax liability	$	(9,126	)	$	(10,266	)

Carryforwards Available to Reduce Future Income Taxes

At December 31, 2017, Comstock had the following carryforwards available to reduce future income taxes:

Types of Carryforward	Years of Expiration Carryforward	Amount
		(In thousands)
Net operating loss - U.S. federal	2018-2037	$	923,736
Net operating loss – state taxes	2020-2037	$	1,517,214
Alternative minimum tax credits	Unlimited	$	1,349

Derivative Financial Instruments and Hedging Activities (Tables)

12 Months Ended

Dec. 31, 2017

Derivative Instruments And Hedging Activities Disclosure [Abstract]

Summary of Outstanding Derivative Financial Instruments

The Company had the following outstanding derivative financial instruments used for oil and natural gas price risk management:

Commodity and Derivative Type	Weighted-Average Contract Price	Contract Volume (MMBtu)	Contract Period
December 31, 2016:
Natural Gas Swap Agreements	$3.37 per MMBtu	23,400,000	2017
December 31, 2017:
Natural Gas Swap Agreements	$3.38 per MMBtu	2,565,000	2018

Supplementary Quarterly Financial Data (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2017

Quarterly Financial Information Disclosure [Abstract]

Schedule of Supplementary Quarterly Financial Data (Unaudited)

	2016
	First			Second			Third			Fourth			Total
	(In thousands, except per share data)
Total oil and gas sales	$	36,163		$	40,715		$	50,330		$	48,498		$	175,706
Operating loss	$	(56,490	)	$	(22,706	)	$	(98,789	)	$	(5,805	)	$	(183,790	)
Net income (loss)	$	(56,577	)	$	4,852		$	(28,476	)	$	(54,933	)	$	(135,134	)
Income (loss) per share:
Basic and diluted	$	(5.71	)	$	0.42		$	(2.32	)	$	(4.48	)	$	(11.52	)

	2017
	First			Second			Third			Fourth			Total
	(In thousands, except per share data)
Total oil and gas sales	$	53,801		$	61,471		$	66,811		$	73,248		$	255,331
Operating income (loss)	$	2,381		$	10,470		$	11,190		$	(24,224	)	$	(183	)
Net loss	$	(22,931	)	$	(21,442	)	$	(24,736	)	$	(42,296	)	$	(111,405	)
Loss per share:
Basic and diluted	$	(1.61	)	$	(1.45	)	$	(1.67	)	$	(2.86	)	$	(7.61	)

Summary of Results of Operations from Non-Routine Items

Results of operations include the following non-routine items of income (expense), which are presented before the effect of income taxes:


	2016
	First			Second			Third			Fourth			Total
	(In thousands)
Gain (loss) on sale of oil and gas properties	$	740		$	(1,647	)	$	(13,196	)	$	(212	)	$	(14,315	)
Net gain (loss) on extinguishment of debt	$	33,380		$	56,196		$	100,540		$	(1,064	)	$	189,052
Impairments of unproved oil and gas properties	$	(7,753	)	$	—		$	(76,391	)	$	—		$	(84,144	)
Impairments of proved oil and gas properties	$	(22,718	)	$	(1,742	)	$	(113	)	$	(2,561	)	$	(27,134	)


	2017
	First			Second		Third			Fourth			Total
	(In thousands)
Gain (loss) on sale of oil and gas properties	$	(24	)	$	—	$	(1,036	)	$	—		$	(1,060	)
Impairments of proved oil and gas properties	$	—		$	—	$	—		$	(43,990	)	$	(43,990	)

- Definition

Tabular disclosure of the results of operations for oil and gas producing activities for the year.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 932
-SubTopic 235
-Section 50
-Paragraph 27
-URI http://asc.fasb.org/extlink&oid=68064819&loc=d3e62352-109447

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 932
-SubTopic 235
-Section 50
-Paragraph 24
-URI http://asc.fasb.org/extlink&oid=68064819&loc=d3e62246-109447

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 932
-SubTopic 235
-Section 50
-Paragraph 23
-URI http://asc.fasb.org/extlink&oid=68064819&loc=d3e62136-109447

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 932
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-10.(a)(17)(ii),(c)(3)(ii)(A)(1))
-URI http://asc.fasb.org/extlink&oid=82851474&loc=d3e511914-122862

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 932
-SubTopic 235
-Section 50
-Paragraph 25
-URI http://asc.fasb.org/extlink&oid=68064819&loc=d3e62259-109447

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 932
-SubTopic 235
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=68064819&loc=d3e62299-109447

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 932
-SubTopic 235
-Section 50
-Paragraph 22
-URI http://asc.fasb.org/extlink&oid=68064819&loc=d3e62094-109447

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 932
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-URI http://asc.fasb.org/extlink&oid=68064819&loc=d3e62395-109447

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (c)(3)
-URI http://asc.fasb.org/extlink&oid=6392692&loc=d3e7535-110849

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 932
-SubTopic 235
-Section 55
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=34713648&loc=d3e63071-109448

+ Details

Oil and Gas Reserves Information (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2017

Extractive Industries [Abstract]

Summary of Changes in Net Quantities of Crude Oil and Natural Gas Reserves

Set forth below is a summary of the changes in Comstock's net quantities of oil and natural gas reserves for each of the three years in the period ended December 31, 2017:

	2015						2016						2017
	Oil (MBbls)			Natural Gas (MMcf)			Oil (MBbls)			Natural Gas (MMcf)			Oil (MBbls)			Natural Gas (MMcf)
Proved Reserves:
Beginning of year		20,854			495,266			9,229			569,596			7,277			872,468
Revisions of previous estimates		(5,096	)		(41,437	)		(406	)		130,416			1,232			33,721
Extensions and discoveries		231			168,539			64			285,076			1			291,881
Sales of minerals in place		(3,671	)		(5,096	)		(222	)		(58,942	)		(7	)		(7,593	)
Production		(3,089	)		(47,676	)		(1,388	)		(53,678	)		(951	)		(73,521	)
End of year		9,229			569,596			7,277			872,468			7,552			1,116,956
Proved Developed Reserves:
Beginning of year		16,247			324,598			9,229			311,130			7,277			321,527
End of year		9,229			311,130			7,277			321,527			7,552			436,114
Proved Undeveloped Reserves:
Beginning of year		4,607			170,668			—			258,466			—			550,941
End of year		—			258,466			—			550,941			—			680,842

Reserves associated with Assets Held for Sale:
Proved Reserves
Beginning of year		16,282			14,716			8,701			9,119			6,950			9,915
End of year		8,701			9,119			6,950			9,915			7,116			10,484
Proved Developed Reserves
Beginning of year		14,028			14,071			8,701			9,119			6,950			9,915
End of year		8,701			9,119			6,950			9,915			7,116			10,484
Proved Undeveloped Reserves
Beginning of year		2,253			645			—			—			—			—
End of year		—			—			—			—			—			—

Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves

The following table sets forth the standardized measure of discounted future net cash flows relating to proved reserves at December 31, 2016 and 2017:

	2016			2017
	(In thousands)
Cash Flows Relating to Proved Reserves:
Future Cash Flows	$	2,267,877		$	3,588,764
Future Costs:
Production		(798,454	)		(986,398	)
Development and Abandonment		(502,848	)		(672,559	)
Future Income Taxes		(6,488	)		5,239
Future Net Cash Flows		960,087			1,935,046
10% Discount Factor		(530,812	)		(1,053,502	)
Standardized Measure of Discounted Future Net Cash Flows	$	429,275		$	881,544
Standardized Measure of Discounted Future Net Cash Flows Related to Assets Held for Sale	$	77,146		$	109,134

Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves

The following table sets forth the changes in the standardized measure of discounted future net cash flows relating to proved reserves for the years ended December 31, 2015, 2016 and 2017:

	2015			2016			2017
	(In thousands)
Standardized Measure, Beginning of Year	$	1,090,660		$	372,139		$	429,275
Net change in sales price, net of production costs		(751,774	)		(45,379	)		326,662
Development costs incurred during the year which were previously estimated		157,390			45,648			119,864
Revisions of quantity estimates		(111,454	)		113,583			57,042
Accretion of discount		114,427			37,251			43,130
Changes in future development and abandonment costs		14,901			5,315			(62,509	)
Changes in timing and other		(44,439	)		(38,071	)		(15,565	)
Extensions and discoveries		56,216			70,149			167,135
Sales of minerals in place		(43,694	)		(22,449	)		(6,027	)
Sales, net of production costs		(163,336	)		(107,253	)		(194,562	)
Net changes in income taxes		53,242			(1,658	)		17,099
Standardized Measure, End of Year	$	372,139		$	429,275		$	881,544

- Definition

Tabular disclosure of the net quantities of an enterprise's interests in proved developed and undeveloped reserves of (a) crude oil (including condensate and natural gas liquids), (b) natural gas (including coal bed methane), (c) synthetic oil, (d) synthetic gas, and (e) other nonrenewable natural resources that are intended to be upgraded during the period as of the beginning of the period, changes in quantities during the period, and as of the end of the period.

+ References + Details

- Definition

Tabular disclosure of the future net cash flows relating to proved oil and gas reserves and oil and gas subject to purchase under long-term agreements in which the enterprise participates in the operation of the properties on which the oil and gas is located or otherwise serves as the producer. This information is presented in aggregate and for each geographic area for which reserve quantities are disclosed.

+ References + Details

Summary of Significant Accounting Policies - Additional Information 1 (Detail)	12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2016
Accounting Policies [Abstract]
2016 Reverse share split		0.2
2016 Reverse share split description	a one for five (1:5) reverse split
Allowance for doubtful accounts	$ 0

Summary of Significant Accounting Policies - Summary of Other Current Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Schedule Of Other Current Assets [Line Items]
Other Current Assets	$ 2,745	$ 1,824
Pipe and oil field equipment inventory
Schedule Of Other Current Assets [Line Items]
Other Current Assets	998	1,183
Production tax refunds receivable
Schedule Of Other Current Assets [Line Items]
Other Current Assets	1,409	303
Other
Schedule Of Other Current Assets [Line Items]
Other Current Assets	$ 338	$ 338

Summary of Significant Accounting Policies - Additional Information 2 (Detail) - USD ($)	Dec. 31, 2017	Dec. 31, 2016
Operations And Summary Of Significant Accounting Policies [Line Items]
Derivative financial instruments, liability		$ 6,000,000
Derivative financial instruments, asset	$ 1,300,000
Fixed Rate Debt
Operations And Summary Of Significant Accounting Policies [Line Items]
Long-term debt, including current portion, Carrying Value	1,100,000,000	1,100,000,000
Level 2 \| Fixed Rate Debt
Operations And Summary Of Significant Accounting Policies [Line Items]
Long-term debt, including current portion, Fair Value	1,200,000,000	$ 1,100,000,000
Fair Value, Measurements, Recurring \| Level 3
Operations And Summary Of Significant Accounting Policies [Line Items]
Financial assets	0
Financial liabilities	$ 0

Summary of Significant Accounting Policies - Additional Information 3 (Detail) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended							12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017	Sep. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operations And Summary Of Significant Accounting Policies [Line Items]
Conversion ratio of oil to natural gas in units of production									One barrel of oil for six thousand cubic feet of natural gas
Impairment of unproved oil and natural gas properties						$ 76,391		$ 7,753		$ 84,144	$ 68,900
Impairment of oil and gas properties		$ 43,990			$ 2,561	113	$ 1,742	22,718	$ 43,990	27,134	$ 801,347
Proceeds from sale of oil and gas properties									1,500	2,100
Loss on sale of oil and gas properties			$ (1,036)	$ (24)	$ (212)	$ (13,196)	$ (1,647)	740	$ (1,060)	(14,315)
Minimum
Operations And Summary Of Significant Accounting Policies [Line Items]
Property and equipment estimated useful lives									3 years
Maximum
Operations And Summary Of Significant Accounting Policies [Line Items]
Property and equipment estimated useful lives									31 years 6 months
Other Properties
Operations And Summary Of Significant Accounting Policies [Line Items]
Impaired oil and gas properties fair value										21,100
South Texas Asset Held for Sale
Operations And Summary Of Significant Accounting Policies [Line Items]
Impairment of oil and gas properties		43,800
Assets held for sale, fair value		$ 198,600							$ 198,600
South Texas Sold Properties
Operations And Summary Of Significant Accounting Policies [Line Items]
Impairment of oil and gas properties								20,800		$ 20,800
Assets held for sale, fair value								$ 42,500
Proceeds from sale of oil and gas properties	$ 25,800

Summary of Significant Accounting Policies - Schedule of Fair Value Impairments, Average Prices of Oil and Gas Properties And Applicable Discount Rates (Detail) $ in Thousands	3 Months Ended							12 Months Ended
	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Sep. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Mar. 31, 2016 USD ($)	Dec. 31, 2015 USD ($) $ / bbl $ / Mcf	Sep. 30, 2015 USD ($) $ / bbl $ / Mcf	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Fair Value And Impairments Oil And Gas Properties [Line Items]
Impairment of oil and gas properties	$ 43,990	$ 2,561	$ 113	$ 1,742	$ 22,718			$ 43,990	$ 27,134	$ 801,347
Oil Properties
Fair Value And Impairments Oil And Gas Properties [Line Items]
Fair Value						$ 3,030	$ 330,257			3,030
Impairment of oil and gas properties						$ 16,036	$ 405,308
Management's Oil Price Outlook \| $ / bbl						73.48	73.70
Management's Gas Price Outlook \| $ / Mcf							4.04
Oil Properties \| Minimum
Fair Value And Impairments Oil And Gas Properties [Line Items]
Annual Discount Rate						10.00%	10.00%
Oil Properties \| Maximum
Fair Value And Impairments Oil And Gas Properties [Line Items]
Annual Discount Rate						20.00%	20.00%
Natural Gas Properties
Fair Value And Impairments Oil And Gas Properties [Line Items]
Fair Value						$ 123,926	$ 61,625			$ 123,926
Impairment of oil and gas properties						$ 238,210	$ 139,406
Management's Oil Price Outlook \| $ / bbl						70.76	75.91
Management's Gas Price Outlook \| $ / Mcf						3.74	3.91
Natural Gas Properties \| Minimum
Fair Value And Impairments Oil And Gas Properties [Line Items]
Annual Discount Rate						10.00%	10.00%
Natural Gas Properties \| Maximum
Fair Value And Impairments Oil And Gas Properties [Line Items]
Annual Discount Rate						20.00%	20.00%

Summary of Significant Accounting Policies - Summary of Accrued Expenses (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Accrued Liabilities, Current [Abstract]
Accrued drilling costs	$ 5,874	$ 7,498
Accrued interest payable	21,277	22,721
Accrued transportation costs	3,269	2,227
Accrued employee compensation	6,449	6,292
Asset retirement obligation – assets held for sale	4,557
Other	1,029	1,628
Total accrued expenses	$ 42,455	$ 40,366

Summary of Significant Accounting Policies - Summary of Changes in Reserve for Future Abandonment Costs (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Asset Retirement Obligations Noncurrent [Abstract]
Reserve for Future Abandonment Costs at beginning of the year	$ 15,804	$ 20,093
New wells placed on production	7	3
Changes in estimates and timing	(1,260)	(553)
Liabilities settled	(77)	(409)
Assets held for sale	(4,557)
Asset divestitures	(320)	(4,268)
Accretion expense	810	938
Reserve for Future Abandonment Costs at end of the year	$ 10,407	$ 15,804

Summary of Significant Accounting Policies - Additional Information 4 (Detail)	12 Months Ended
	Dec. 31, 2017 USD ($) Segment Customer $ / shares shares	Dec. 31, 2016 USD ($) Customer $ / shares shares	Dec. 31, 2015 USD ($) Customer shares
Operations And Summary Of Significant Accounting Policies [Line Items]
Number of operating segments \| Segment	1
General and administrative expenses reimbursements of overhead costs	$ 11,700,000	$ 12,400,000	$ 13,900,000
Performance multiplier, minimum	0.00%
Performance multiplier, maximum	200.00%
Warrants for Common Stock exercise price \| $ / shares	$ 0.01	$ 0.01
Participating securities that share in losses \| shares	0	0	0
Interest costs, capitalized during period	$ 0	$ 0	$ 900,000
Interest paid in-kind	38,073,000	11,860,000
Convertible Notes
Operations And Summary Of Significant Accounting Policies [Line Items]
Interest paid in-kind	$ 38,100,000	$ 11,900,000
Restricted Stock
Operations And Summary Of Significant Accounting Policies [Line Items]
Shares of unvested restricted stock outstanding \| shares	619,867	354,986	314,048
Major Oil and Natural Gas Purchaser
Operations And Summary Of Significant Accounting Policies [Line Items]
Number of major customers of oil and gas sales \| Customer	4	4	2
Major Oil and Natural Gas Purchaser One
Operations And Summary Of Significant Accounting Policies [Line Items]
Percentage accounted of oil and gas sales	34.00%	42.00%	52.00%
Major Oil and Natural Gas Purchaser Two
Operations And Summary Of Significant Accounting Policies [Line Items]
Percentage accounted of oil and gas sales	17.00%	17.00%	25.00%
Major Oil and Natural Gas Purchaser Three
Operations And Summary Of Significant Accounting Policies [Line Items]
Percentage accounted of oil and gas sales	16.00%	14.00%
Major Oil and Natural Gas Purchaser Four
Operations And Summary Of Significant Accounting Policies [Line Items]
Percentage accounted of oil and gas sales	15.00%	12.00%

Summary of Significant Accounting Policies - Basic and Diluted Earnings Per Share (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Earnings Per Share [Abstract]
Basic and Diluted Net Income (Loss) Attributable to Common Stock									$ (111,405)	$ (135,134)	$ (1,047,109)
Basic and diluted weighted average shares outstanding									14,644	11,729	9,223
Net loss per share – basic and diluted	$ (2.86)	$ (1.67)	$ (1.45)	$ (1.61)	$ (4.48)	$ (2.32)	$ 0.42	$ (5.71)	$ (7.61)	$ (11.52)	$ (113.53)

Summary of Significant Accounting Policies - Weighted Average Shares of Unvested Restricted Stock (Detail) - shares shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Unvested restricted stock	612	344	293

Summary of Significant Accounting Policies - Common Stock Stock Options and Convertible Stock Anti-Dilutive to Earnings Excluded from Weighted Average Shares Used in Computation of Earning Per Share (Detail) shares in Thousands, EquityUnit in Thousands	12 Months Ended
	Dec. 31, 2017 EquityUnit $ / shares $ / EquityUnit shares	Dec. 31, 2016 EquityUnit $ / shares $ / EquityUnit shares	Dec. 31, 2015 EquityUnit $ / shares $ / EquityUnit shares
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Weighted average stock options \| shares		11	20
Weighted average warrants for common stock \| shares	463	337
Weighted average PSUs \| EquityUnit	274	136	136
Weighted average grant date fair value per unit \| $ / EquityUnit	17.12	22.17	35.35
Weighted average contingently convertible shares \| shares	37,046	11,574
Options
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Weighted average exercise price per share \| $ / shares		$ 166.10	$ 164.75
Warrants for Common Stock
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Weighted average exercise price per share \| $ / shares	$ 0.01	0.01
Contingently Convertible Shares
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Weighted average exercise price per share \| $ / shares	$ 12.32	$ 12.32

Summary of Significant Accounting Policies - Cash Payments Made for Interest and Income Taxes (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash Payments [Abstract]
Interest payments	$ 73,941	$ 105,449	$ 94,177
Income tax payments	$ 3		$ 77

Acquisitions and Dispositions of Oil and Gas Properties - Additional Information (Detail)	1 Months Ended			3 Months Ended					12 Months Ended
	Dec. 31, 2016 USD ($)	Jan. 31, 2016 a Well	Jul. 31, 2015 USD ($)	Dec. 31, 2017 USD ($) a	Dec. 31, 2016 USD ($)	Sep. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Mar. 31, 2016 USD ($)	Dec. 31, 2017 USD ($) a Well	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Business Acquisition [Line Items]
JV acreage cost reimbursement working interest per well				25.00%					25.00%
Bossier shale JV wells gross wells \| Well									4
Working interest for JV acreage and infrastructure									50.00%
Proceeds received to meet or exceed JV production targets									$ 400,000
Proceeds to be received per JV drilled well									80,000
Impairment of oil and gas properties				$ 43,990,000	$ 2,561,000	$ 113,000	$ 1,742,000	$ 22,718,000	43,990,000	$ 27,134,000	$ 801,347,000
Net proceeds from sale of oil and gas properties									1,500,000	2,100,000
Loss on sale of oil and gas properties										1,600,000
Property exchange net acres received \| a		3,637
Property exchange gross wells received \| Well		4
Property exchange net wells received \| a		3.5
Property exchange net acres disposed \| a		2,547
Property exchange gross wells disposed \| Well		7
Property exchange net wells disposed \| a		5.3
Gain on property exchange of oil and gas properties										700,000
South Texas Sold Properties
Business Acquisition [Line Items]
Impairment of oil and gas properties								$ 20,800,000		20,800,000
Net proceeds from sale of oil and gas properties	$ 25,800,000
Loss on sale of oil and gas properties										$ 13,400,000
South Texas Asset Held for Sale
Business Acquisition [Line Items]
Impairment of oil and gas properties				43,800,000
Asset retirement liability				$ 4,600,000					$ 4,600,000
Burleson County, Texas
Business Acquisition [Line Items]
Net proceeds from sale of oil and gas properties			$ 102,500,000
Loss on sale of oil and gas properties			$ 112,100,000
Caddo Parish Louisiana
Business Acquisition [Line Items]
Joint venture approximate net acreage \| a				6,300					6,300
Harrison County Texas
Business Acquisition [Line Items]
Joint venture approximate net acreage \| a				5,700					5,700
Proceeds to be received for acreage and infrastructure									$ 1,400,000
Sabine Parish Louisiana
Business Acquisition [Line Items]
Proceeds to be received for acreage and infrastructure									$ 1,100,000
Working Interest Change Upon Commencement of 13th Well
Business Acquisition [Line Items]
JV acreage cost reimbursement working interest per well				40.00%					40.00%

Acquisitions and Dispositions of Oil and Gas Properties - Results of Operations for Properties (Detail) - USD ($)
$ in Thousands

12 Months Ended

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Oil And Gas Properties Sold [Abstract]

Total oil and gas sales

$ 48,949

$ 63,303

$ 157,956

Total operating expenses

^[1]

(44,861)

(80,467)

(274,651)

Operating income (loss)

$ 4,088

$ (17,164)

$ (116,695)

[1]	Includes direct operating expenses, depreciation, depletion and amortization and exploration expense. Excludes interest expense, general and administrative expenses and depreciation, depletion and amortization expense subsequent to the date the assets were designated as held for sale.

Oil and Gas Producing Activities - Capitalized Costs Related to Oil and Gas Property Acquisition Exploration and Development Activities (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Proved properties:
Leasehold costs	$ 491,507	$ 662,022
Wells and related equipment and facilities	2,140,243	3,135,079
Accumulated depreciation depletion and amortization	(2,032,927)	(3,009,236)
Capitalized costs, oil and gas producing activities, net, total	$ 598,823	$ 787,865

Oil and Gas Producing Activities - Costs Incurred Related to Oil and Gas Property Acquisition Exploration and Development Activities (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Oil And Gas Exploration And Production Industries Disclosures [Abstract]
Unproved property acquisitions			$ 12,972
Development costs	$ 177,432	$ 58,587	221,265
Exploration costs			12,265
Costs incurred, acquisition of oil and gas properties, total	$ 177,432	$ 58,587	$ 246,502

Long-term Debt - Long-term Debt (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Sep. 06, 2016
Debt Instrument [Line Items]
Debt issuance costs, net of amortization	$ (10,685)	$ (16,183)
Long-term Debt	1,110,529	1,044,506
10% Senior Secured Toggle Notes due 2020
Debt Instrument [Line Items]
Principal	697,195	697,195
Discount, net of amortization	(8,901)	(11,955)
7¾% Senior Notes due 2019
Debt Instrument [Line Items]
Principal	17,959	17,959	$ 18,000
Premium, net of amortization	65	118
7¾% Convertible Second Lien PIK Notes due 2019
Debt Instrument [Line Items]
Principal	284,442	268,432
Accrued interest payable in kind	5,572	6,645
Discount, net of amortization	(38,748)	(61,230)
9½% Senior Notes due 2020
Debt Instrument [Line Items]
Principal	4,860	4,860	$ 4,900
Discount, net of amortization	(70)	(98)
9½% Convertible Second Lien PIK Notes due 2020
Debt Instrument [Line Items]
Principal	187,062	174,182
Accrued interest payable in kind	817	735
Discount, net of amortization	(31,844)	(38,959)
10% Senior Notes due 2020
Debt Instrument [Line Items]
Principal	$ 2,805	$ 2,805

Long-term Debt - Long-term Debt (Parenthetical) (Detail)	Dec. 31, 2017	Dec. 31, 2016
10% Senior Secured Toggle Notes due 2020
Debt Instrument [Line Items]
Interest rate on debt instrument	10.00%	10.00%
7¾% Senior Notes due 2019
Debt Instrument [Line Items]
Interest rate on debt instrument	7.75%	7.75%
7¾% Convertible Second Lien PIK Notes due 2019
Debt Instrument [Line Items]
Interest rate on debt instrument	7.75%	7.75%
9½% Senior Notes due 2020
Debt Instrument [Line Items]
Interest rate on debt instrument	9.50%	9.50%
9½% Convertible Second Lien PIK Notes due 2020
Debt Instrument [Line Items]
Interest rate on debt instrument	9.50%	9.50%
10% Senior Notes due 2020
Debt Instrument [Line Items]
Interest rate on debt instrument	10.00%	10.00%

Long-term Debt - Principal Amount of Debt and Associated Paid-in Kind Interest Payable by Year of Maturity (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Sep. 06, 2016
Debt Instrument [Line Items]
2018, Principal and paid-in kind interest payable	$ 0
2019, Principal and paid-in kind interest payable	307,973
2020, Principal and paid-in kind interest payable	892,739
2021, Principal and paid-in kind interest payable	0
2022, Principal and paid-in kind interest payable	0
Thereafter, Principal and paid-in kind interest payable	0
Total, Principal and paid-in kind interest payable	1,200,712
10% Senior Secured Toggle Notes due 2020
Debt Instrument [Line Items]
2018, Principal	0
2019, Principal	0
2020, Principal	697,195
2021, Principal	0
2022, Principal	0
Thereafter, Principal	0
Long term debt principal amount	697,195	$ 697,195
7¾% Convertible Second Lien PIK Notes due 2019
Debt Instrument [Line Items]
Long term debt principal amount	284,442	268,432
2018, Principal and paid-in kind interest payable	0
2019, Principal and paid-in kind interest payable	290,014
2020, Principal and paid-in kind interest payable	0
2021, Principal and paid-in kind interest payable	0
2022, Principal and paid-in kind interest payable	0
Thereafter, Principal and paid-in kind interest payable	0
Total, Principal and paid-in kind interest payable	290,014
9½% Convertible Second Lien PIK Notes due 2020
Debt Instrument [Line Items]
Long term debt principal amount	187,062	174,182
2018, Principal and paid-in kind interest payable	0
2019, Principal and paid-in kind interest payable	0
2020, Principal and paid-in kind interest payable	187,879
2021, Principal and paid-in kind interest payable	0
2022, Principal and paid-in kind interest payable	0
Thereafter, Principal and paid-in kind interest payable	0
Total, Principal and paid-in kind interest payable	187,879
10% Senior Notes due 2020
Debt Instrument [Line Items]
2018, Principal	0
2019, Principal	0
2020, Principal	2,805
2021, Principal	0
2022, Principal	0
Thereafter, Principal	0
Long term debt principal amount	2,805	2,805
7¾% Senior Notes due 2019
Debt Instrument [Line Items]
2018, Principal	0
2019, Principal	17,959
2020, Principal	0
2021, Principal	0
2022, Principal	0
Thereafter, Principal	0
Long term debt principal amount	17,959	17,959	$ 18,000
9½% Senior Notes due 2020
Debt Instrument [Line Items]
2018, Principal	0
2019, Principal	0
2020, Principal	4,860
2021, Principal	0
2022, Principal	0
Thereafter, Principal	0
Long term debt principal amount	$ 4,860	$ 4,860	$ 4,900

Long-term Debt - Principal Amount of Debt and Associated Paid-in Kind Interest Payable by Year of Maturity (Parenthetical) (Detail)	Dec. 31, 2017	Dec. 31, 2016
10% Senior Secured Toggle Notes due 2020
Debt Instrument [Line Items]
Interest rate on debt instrument	10.00%	10.00%
7¾% Convertible Second Lien PIK Notes due 2019
Debt Instrument [Line Items]
Interest rate on debt instrument	7.75%	7.75%
9½% Convertible Second Lien PIK Notes due 2020
Debt Instrument [Line Items]
Interest rate on debt instrument	9.50%	9.50%
10% Senior Notes due 2020
Debt Instrument [Line Items]
Interest rate on debt instrument	10.00%	10.00%
7¾% Senior Notes due 2019
Debt Instrument [Line Items]
Interest rate on debt instrument	7.75%	7.75%
9½% Senior Notes due 2020
Debt Instrument [Line Items]
Interest rate on debt instrument	9.50%	9.50%

Long-term Debt - Additional Information (Detail)		3 Months Ended				8 Months Ended	12 Months Ended
Long-term Debt - Additional Information (Detail)	Sep. 06, 2016 USD ($) shares	Dec. 31, 2016 USD ($)	Sep. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Mar. 31, 2016 USD ($)	Sep. 05, 2016 USD ($) shares	Dec. 31, 2017 USD ($) Day $ / shares	Dec. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Debt Instrument [Line Items]
Gain on extinguishment of debt		$ (1,064,000)	$ 100,540,000	$ 56,196,000	$ 33,380,000			$ 189,052,000	$ 78,741,000
Unamortized debt issuance costs		$ 16,183,000					$ 10,685,000	$ 16,183,000
Loss from write-off of deferred loan costs									3,700,000
Exchange Offer
Debt Instrument [Line Items]
Percentage of outstanding senior notes	98.00%
Warrants exercisable \| shares	1,917,342
10% Senior Secured Toggle Notes due 2020
Debt Instrument [Line Items]
Interest payment terms							payable on March 15 and September 15, and the notes mature on March 15, 2020
Maturity of senior notes							Mar. 15, 2020
Accrued interest by issuing additional notes							$ 75,000,000
Interest rate on senior notes, payment in kind							12.25%
Additional notes outstanding							$ 91,900,000
Interest rate on senior notes		10.00%					10.00%	10.00%
Principal		$ 697,195,000					$ 697,195,000	$ 697,195,000
10% Senior Secured Toggle Notes due 2020 \| Exchange Offer
Debt Instrument [Line Items]
Principal amount of notes issued	$ 697,200,000
Interest rate on senior notes	10.00%
Transaction costs								$ 4,500,000
7¾% Convertible Second Lien PIK Notes due 2019
Debt Instrument [Line Items]
Interest payment terms							payable on April 1 and October 1
Maturity of senior notes							Apr. 01, 2019
Interest rate on senior notes		7.75%					7.75%	7.75%
Principal		$ 268,432,000					$ 284,442,000	$ 268,432,000
7¾% Convertible Second Lien PIK Notes due 2019 \| Exchange Offer
Debt Instrument [Line Items]
Principal amount of notes issued	$ 270,600,000
Interest rate on senior notes	7.75%
9½% Convertible Second Lien PIK Notes due 2020
Debt Instrument [Line Items]
Interest payment terms							payable on June 15 and December 15
Maturity of senior notes							Jun. 15, 2020
Interest payment commencing date							Dec. 15, 2016
Interest rate on senior notes		9.50%					9.50%	9.50%
Principal		$ 174,182,000					$ 187,062,000	$ 174,182,000
9½% Convertible Second Lien PIK Notes due 2020 \| Exchange Offer
Debt Instrument [Line Items]
Principal amount of notes issued	$ 169,700,000
Interest rate on senior notes	9.50%
Convertible Second Lien PIK Notes
Debt Instrument [Line Items]
Debt instrument convertible conversion ratio							0.0812
Debt instrument convertible threshold consecutive trading days period \| Day							15
Convertible Second Lien PIK Notes \| Exchange Offer
Debt Instrument [Line Items]
Unamortized debt issuance costs	$ 6,500,000
Convertible Second Lien PIK Notes \| Minimum
Debt Instrument [Line Items]
Daily volume weighted average price \| $ / shares							$ 12.32
10% Senior Secured Notes due 2020
Debt Instrument [Line Items]
Principal	$ 2,800,000
10% Senior Secured Notes due 2020 \| Exchange Offer
Debt Instrument [Line Items]
Interest rate on senior notes	10.00%
Principal amount of notes repurchased	$ 697,200,000
Gain (loss) on exchange of debt	0
7¾% Senior Notes due 2019
Debt Instrument [Line Items]
Interest rate on senior notes		7.75%					7.75%	7.75%
Principal amount of notes repurchased						$ 87,500,000			23,900,000
Principal	$ 18,000,000	$ 17,959,000					$ 17,959,000	$ 17,959,000
7¾% Senior Notes due 2019 \| Exchange Offer
Debt Instrument [Line Items]
Interest rate on senior notes	7.75%
Principal amount of notes repurchased	$ 270,600,000
9½% Senior Notes due 2020
Debt Instrument [Line Items]
Interest rate on senior notes		9.50%					9.50%	9.50%
Principal amount of notes repurchased						$ 19,800,000			105,600,000
Principal	$ 4,900,000	$ 4,860,000					$ 4,860,000	$ 4,860,000
Aggregate purchase price of debt									42,700,000
9½% Senior Notes due 2020 \| Exchange Offer
Debt Instrument [Line Items]
Interest rate on senior notes	9.50%
Principal amount of notes repurchased	$ 169,700,000
7 3/4% Senior Notes due 2019 and 9 1/2% Senior Notes due 2020
Debt Instrument [Line Items]
Gain on extinguishment of debt								89,600,000
Common stock shares exchanged for repayment of principal amount \| shares						2,748,403
Gain on repurchased amount of notes									$ 82,400,000
7 3/4% Senior Notes due 2019 and 9 1/2% Senior Notes due 2020 \| Exchange Offer
Debt Instrument [Line Items]
Gain on extinguishment of debt								$ 106,200,000
7 3/4% Senior Notes due 2019 and 9 1/2% Senior Notes due 2020 \| Payment In Cash
Debt Instrument [Line Items]
Senior notes exchanged in cash						$ 3,500,000

Long-term Debt - Additional Information 1 (Detail) - Revolving Credit Facility - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Bank credit facility		$ 50,000,000
Maturity of credit facility		Mar. 04, 2019
Credit facility amount outstanding		$ 0
Spread rate over LIBOR for interest rate on credit facility		2.50%
Stated percentage over federal funds rate to calculate base rate		0.50%
Stated percentage over 30 day LIBOR to calculate base rate		1.00%
Spread rate over base rate for interest rate on credit facility		1.50%
Commitment fee on unused borrowing base		0.50%
Ratio of current assets to current liabilities		90.00%
Asset coverage ratio		250.00%
Scenario Forecast
Debt Instrument [Line Items]
Ratio of current assets to current liabilities	100.00%

Commitments and Contingencies - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Commitments And Contingencies Disclosure [Abstract]
Rent expense under noncancelable operating leases	$ 1.6	$ 1.5	$ 1.5
Natural gas transportation and treating agreements	through July 2019
Maximum commitments under natural gas transportation and treating agreements	$ 2.4
Contract term related to drilling services	through June 2018
Commitments for contracted drilling services	$ 7.4

Commitments and Contingencies - Minimum Future Payments under Leases (Detail) $ in Thousands	Dec. 31, 2017 USD ($)
Leases [Abstract]
2018	$ 1,560
2019	1,560
2020	1,560
2021	1,560
Operating Leases, Future Minimum Payments Due, Total	$ 6,240

Stockholders' Equity - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Stockholders Equity [Line Items]
Common stock, shares authorized	75,000,000	75,000,000
Common stock, par value	$ 0.50	$ 0.50
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, par value per share	$ 10.00	$ 10.00
Preferred stock, shares outstanding	0	0
Debt conversion, convertible instrument, principal amount	$ 9.9	$ 2.1
Warrants issued to acquire common stock		1,917,342
Exercise price of warrants for common stock	$ 0.01	$ 0.01
Warrants exercised	1,502,255
Warrants outstanding	415,087
Common Stock
Stockholders Equity [Line Items]
Debt conversion, converted instrument, shares of common stock issued	826,327	176,175
Warrants exercised	247,000	1,256,000

Stock-based Compensation - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense recognized	$ 5,923	$ 4,660	$ 8,149
General and Administrative Expense
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense recognized	$ 5,900	$ 4,700	$ 8,100
2009 Long Term Incentive Plan
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Long-term Incentive Plan shares available for future awards of performance share units, restricted stock grants or other equity awards	1,983,864

Stock-based Compensation - Additional Information 1 (Detail) $ / shares in Units, $ in Millions	12 Months Ended			24 Months Ended
	Dec. 31, 2017 USD ($) Unit $ / shares $ / EquityUnit shares	Dec. 31, 2016 USD ($) Unit $ / shares $ / EquityUnit	Dec. 31, 2015 USD ($) Unit $ / shares $ / EquityUnit	Dec. 31, 2019 Unit
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Performance multiplier, minimum	0.00%
Performance multiplier, maximum	200.00%
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Compensation expense recognized	$ 3.9	$ 3.4	$ 6.0
Grant date fair value of share units, per share \| $ / shares	$ 11.11	$ 5.46	$ 26.70
Unrecognized compensation cost related to unvested restricted stock	$ 3.8
Period in which compensation cost expected to be recognized	1 year 9 months 18 days
Fair value of restricted stock vested	$ 1.7	$ 1.3	$ 3.7
Potential Performance Shares (PSU)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Compensation expense recognized	$ 2.0	$ 1.3	$ 2.1
Performance Periods	The performance periods consist of one year, two years and three years, respectively
Number of units granted \| Unit	241,814	60,015	94,250
Performance share units grant date fair value	$ 4.4	$ 0.4	$ 0.7
Grant date fair value of share units, per unit \| $ / EquityUnit	18.17	7.00	7.30
Minimum final number of shares of common stock issuable based on performance multiplier \| shares	0
Maximum final number of shares of common stock issuable based on performance multiplier \| shares	269,300
Performance multiplier, minimum	0.00%
Performance multiplier, maximum	200.00%
Unrecognized expense, performance share units	$ 3.0
Term for Amortization of Performance Share Compensation cost	through December 31, 2019.
Potential Performance Shares (PSU) \| Scenario Forecast
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of Units, Earned \| Unit				85,987
Number of Units, Forfeited \| Unit				10,857
Minimum \| Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Amortized vesting period of restricted stock	1 year
Minimum \| Potential Performance Shares (PSU)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Amortized vesting period of restricted stock	1 year
Maximum \| Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Amortized vesting period of restricted stock	3 years
Maximum \| Potential Performance Shares (PSU)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Amortized vesting period of restricted stock	3 years

Stock-based Compensation - Summary of Restricted Stock Activity (Detail) - Restricted Stock - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Beginning Balance, Number of Shares, Outstanding	354,986	314,048
Number of Shares, Granted	500,002
Number of Shares, Vested	(185,652)
Number of Shares, Forfeitures	(49,469)
Ending Balance, Number of Shares, Outstanding	619,867	354,986	314,048
Beginning Balance, Weighted Average Grant Price, Outstanding	$ 15.60
Weighted Average Grant Price, Granted	11.11	$ 5.46	$ 26.70
Weighted Average Grant Price, Vested	18.88
Weighted Average Grant Price, Forfeitures	13.10
Ending Balance, Weighted Average Grant Price, Outstanding	$ 11.14	$ 15.60

Stock-based Compensation - Summary of Significant Assumptions Use to Value PSUs (Detail) - Potential Performance Shares (PSU)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Performance share units, Risk free interest rate	1.60%	0.90%	1.10%
Performance share units, Minimum volatility	37.00%	47.00%	37.00%
Performance share units, Maximum volatility	134.00%	92.00%	65.00%

Stock-based Compensation - Summary of PSU Activity (Detail) (Potential Performance Shares (PSU)) - Performance Share Units (PSU)	12 Months Ended
	Dec. 31, 2017 Unit $ / EquityUnit	Dec. 31, 2016 Unit $ / EquityUnit	Dec. 31, 2015 Unit $ / EquityUnit
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Beginning Balance, Number of Units, Outstanding \| Unit	134,650
Number of Units, Granted \| Unit	241,814	60,015	94,250
Number of Units, Unearned or forfeited \| Unit	(94,664)
Ending Balance, Number of Units, Outstanding \| Unit	281,800	134,650
Beginning Balance, Weighted Average Grant Price, Outstanding \| $ / EquityUnit	22.17
Weighted Average Grant Price, Granted \| $ / EquityUnit	18.17	7.00	7.30
Weighted Average Grant Price, Unearned or forfeited \| $ / EquityUnit	27.01
Ending Balance, Weighted Average Grant Price, Outstanding \| $ / EquityUnit	17.12	22.17

Retirement Plan - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Compensation And Retirement Disclosure [Abstract]
Matching contributions to the plan	$ 760,590	$ 758,000	$ 888,000

Income Taxes - Income Tax Provision (Benefit) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Current - Federal	$ (19,086)	$ 0	$ 0
Current - State	136	64	804
Deferred - Federal			(149,171)
Deferred - State	1,006	7,105	(6,078)
Total	$ (17,944)	$ 7,169	$ (154,445)

Income Taxes - Additional Information (Detail) - USD ($) $ in Thousands		12 Months Ended
	Jan. 01, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes [Line Items]
Customary rate			35.00%	35.00%	35.00%
Additional federal and state valuation allowance on net operating loss carryforwards			$ 41,100
Federal net operating losses expired			$ 1,500
Deferred federal tax, Remeasurement Rate			21.00%
Deferred federal tax, Remeasurement Value			$ 140,400
Cumulative common stock ownership change over three year period that would limit federal and state net operating loss carry forwards			50.00%
Subsequent Event
Income Taxes [Line Items]
Operating losses carryforward indefinitely with no carryback as percentage of taxable income	80.00%
Limitations on deduction for interest expense as percentage of taxable income	70.00%
Refundable unused AMT credit carryforward, Percentage	50.00%
Refundable unused alternative minimum tax credit carryforward years	2018 through 2020
Refundable unused AMT credit carryforward, Valuation Allowance	$ 19,100
Refundable unused AMT credit carryforward, year fully refunded by	2021
U.S. Federal
Income Taxes [Line Items]
Net operating loss, Tax Credit Carryforward, Amount			$ 923,736
State Taxes
Income Taxes [Line Items]
Net operating loss, Tax Credit Carryforward, Amount			1,517,214
Valuation allowance on net operating loss carryforwards			$ 1,400,000
Scenario Forecast
Income Taxes [Line Items]
Customary rate		21.00%

Income Taxes - Income Tax Expense Benefit Income Tax Reconciliation (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Tax benefit at statutory rate	$ (45,272)	$ (44,788)	$ (420,544)
Tax effect of:
Effect of the Tax Cuts and Jobs Act net of valuation allowance	(19,086)
Valuation allowance on deferred tax assets	41,116	69,890	283,585
State income taxes, net of federal benefit	(892)	(18,860)	(18,218)
Nondeductible stock-based compensation	1,408	73	539
Net operating loss expirations	1,548
Other	3,234	854	193
Total	$ (17,944)	$ 7,169	$ (154,445)

Income Taxes - Difference Between Customary Rate and Effective Tax Rate on Income Before Income Taxes Due (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Tax at statutory rate	35.00%	35.00%	35.00%
Tax effect of:
Effect of the Tax Cuts and Jobs Act net of valuation allowance	14.80%
Valuation allowance on deferred tax assets	(31.80%)	(54.60%)	(23.50%)
State taxes, net of federal tax benefit	0.70%	14.70%	1.40%
Nondeductible compensation	(1.10%)	(0.10%)
Net operating loss expirations	(1.20%)
Other	(2.50%)	(0.60%)
Effective tax rate	13.90%	(5.60%)	12.90%

Income Taxes - Tax Effects of Significant Temporary Differences Representing Net Deferred Tax Asset and Liability (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Deferred tax assets:
Property and equipment		$ 10,536
Asset retirement obligation	$ 3,489	4,628
Net operating loss carryforwards	289,803	339,914
Alternative minimum tax carryforward	1,349	20,435
Unrealized hedging loss		2,110
Gain on debt exchange and original issue discount	4,336	16,169
Other	3,782	8,523
Noncurrent deferred tax assets	302,759	402,315
Valuation allowance on deferred tax assets	(298,539)	(398,120)
Deferred tax assets	4,220	4,195
Deferred tax liabilities:
Property and equipment	(11,878)	(9,203)
Unrealized hedging income	(277)
Other	(2,331)	(4,118)
Deferred tax liabilities	(14,486)	(13,321)
Net deferred tax liability	$ (10,266)	$ (9,126)

Income Taxes - Carryforwards Available to Reduce Future Income Taxes (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Carryforward Available To Reduce Future Income Taxes [Line Items]
Alternative minimum tax credits carryforward	$ 1,349	$ 20,435
U.S. Federal
Carryforward Available To Reduce Future Income Taxes [Line Items]
Net operating loss, Years of Expiration Carryforward	2018-2037
Net operating loss, Tax Credit Carryforward, Amount	$ 923,736
State Taxes
Carryforward Available To Reduce Future Income Taxes [Line Items]
Net operating loss, Years of Expiration Carryforward	2020-2037
Net operating loss, Tax Credit Carryforward, Amount	$ 1,517,214
Years of Expiration Carryforward Unlimited
Carryforward Available To Reduce Future Income Taxes [Line Items]
Alternative minimum tax credits carryforward	$ 1,349

Derivative Financial Instruments and Hedging Activities - Summary of Outstanding Derivative Financial Instruments (Detail) - Natural Gas Swap Agreements	12 Months Ended
	Dec. 31, 2017 MMBTU $ / MMBTU	Dec. 31, 2016 MMBTU $ / MMBTU
Derivative [Line Items]
Commodity Derivatives Weighted Average Contract Price \| $ / MMBTU	3.38	3.37
Commodity Derivatives Contract Volume \| MMBTU	2,565,000	23,400,000
Commodity Derivatives Contract Period	2018	2017

Derivative Financial Instruments and Hedging Activities - Additional Information (Detail)		12 Months Ended
	Jan. 01, 2018 MMBTU $ / MMBTU	Dec. 31, 2017 USD ($) MMBTU $ / MMBTU	Dec. 31, 2016 USD ($) MMBTU $ / MMBTU	Dec. 31, 2015 USD ($)
Derivative Instruments And Hedging Activities [Line Items]
Cash flow hedges derivative instruments		$ 0
Gain on derivative financial instruments		16,800,000		$ 2,700,000
Loss on derivative financial instruments			$ 5,400,000
Cash settlements of derivative financial instruments		9,405,000	2,120,000	$ 1,230,000
Derivative asset at fair value		1,300,000
Derivative asset at carrying value		1,300,000
Derivative asset current at carrying value		$ 1,318,000
Derivative liability at fair value			6,000,000
Derivative liability at carrying value			6,000,000
Derivative liability current at carrying value			$ 6,030,000
Natural Gas Swap Agreements
Derivative Instruments And Hedging Activities [Line Items]
Commodity derivatives natural gas volumes hedged \| MMBTU		2,565,000	23,400,000
Average Fixed NYMEX price \| $ / MMBTU		3.38	3.37
Natural Gas Swap Agreements \| Subsequent Event
Derivative Instruments And Hedging Activities [Line Items]
Commodity derivatives natural gas volumes hedged \| MMBTU	21,600,000
Average Fixed NYMEX price \| $ / MMBTU	3.00
Contract beginning dates	March and April 2018
Contract expiration dates	February and March 2019

Supplementary Quarterly Financial Data (Unaudited) - Schedule of Supplementary Quarterly Financial Data (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Data [Abstract]
Total oil and gas sales	$ 73,248	$ 66,811	$ 61,471	$ 53,801	$ 48,498	$ 50,330	$ 40,715	$ 36,163	$ 255,331	$ 175,706	$ 252,422
Operating income (loss)	(24,224)	11,190	10,470	2,381	(5,805)	(98,789)	(22,706)	(56,490)	(183)	(183,790)	(1,165,654)
Net income (loss)	$ (42,296)	$ (24,736)	$ (21,442)	$ (22,931)	$ (54,933)	$ (28,476)	$ 4,852	$ (56,577)	$ (111,405)	$ (135,134)	$ (1,047,109)
Income (loss) per share:
Basic and diluted	$ (2.86)	$ (1.67)	$ (1.45)	$ (1.61)	$ (4.48)	$ (2.32)	$ 0.42	$ (5.71)	$ (7.61)	$ (11.52)	$ (113.53)

Supplementary Quarterly Financial Data (Unaudited) - Summary of Results of Operations from Non-Routine Items (Detail) - USD ($) $ in Thousands	3 Months Ended							12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Data [Abstract]
Gain (loss) on sale of oil and gas properties		$ (1,036)	$ (24)	$ (212)	$ (13,196)	$ (1,647)	$ 740	$ (1,060)	$ (14,315)
Net gain on extinguishment of debt				(1,064)	100,540	56,196	33,380		189,052	$ 78,741
Impairments of unproved oil and gas properties					(76,391)		(7,753)		(84,144)	(68,900)
Impairments of proved oil and gas properties	$ (43,990)			$ (2,561)	$ (113)	$ (1,742)	$ (22,718)	$ (43,990)	$ (27,134)	$ (801,347)

Oil and Gas Reserves Information (Unaudited) - Summary of Changes in Net Quantities of Crude Oil and Natural Gas Reserves (Detail)	12 Months Ended
	Dec. 31, 2017 MBbls MMcf	Dec. 31, 2016 MBbls MMcf	Dec. 31, 2015 MBbls MMcf	Dec. 31, 2014 MBbls MMcf
Oil (MBbls)
Proved Reserves:
Beginning of year \| MBbls	7,277	9,229	20,854
Revisions of previous estimates \| MBbls	1,232	(406)	(5,096)
Extensions and discoveries \| MBbls	1	64	231
Sales of minerals in place \| MBbls	(7)	(222)	(3,671)
Production \| MBbls	(951)	(1,388)	(3,089)
End of year \| MBbls	7,552	7,277	9,229
Proved Developed Reserves:
Proved Developed Reserves \| MBbls	7,552	7,277	9,229	16,247
Proved Undeveloped Reserves:
Proved Undeveloped Reserves \| MBbls				4,607
Oil (MBbls) \| Assets Held for Sale
Proved Reserves:
Beginning of year \| MBbls	6,950	8,701	16,282
End of year \| MBbls	7,116	6,950	8,701
Proved Developed Reserves:
Proved Developed Reserves \| MBbls	7,116	6,950	8,701	14,028
Proved Undeveloped Reserves:
Proved Undeveloped Reserves \| MBbls				2,253
Natural Gas (MMcf)
Proved Reserves:
Beginning of year \| MMcf	872,468	569,596	495,266
Revisions of previous estimates \| MMcf	33,721	130,416	(41,437)
Extensions and discoveries \| MMcf	291,881	285,076	168,539
Sales of minerals in place \| MMcf	(7,593)	(58,942)	(5,096)
Production \| MMcf	(73,521)	(53,678)	(47,676)
End of year \| MMcf	1,116,956	872,468	569,596
Proved Developed Reserves:
Proved Developed Reserves \| MMcf	436,114	321,527	311,130	324,598
Proved Undeveloped Reserves:
Proved Undeveloped Reserves \| MMcf	680,842	550,941	258,466	170,668
Natural Gas (MMcf) \| Assets Held for Sale
Proved Reserves:
Beginning of year \| MMcf	9,915	9,119	14,716
End of year \| MMcf	10,484	9,915	9,119
Proved Developed Reserves:
Proved Developed Reserves \| MMcf	10,484	9,915	9,119	14,071
Proved Undeveloped Reserves:
Proved Undeveloped Reserves \| MMcf				645

Oil and Gas Reserves Information (Unaudited) - Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Flows Relating to Proved Reserves:
Future Cash Flows	$ 3,588,764	$ 2,267,877
Future Costs:
Production	(986,398)	(798,454)
Development and Abandonment	(672,559)	(502,848)
Future Income Taxes	5,239	(6,488)
Future Net Cash Flows	1,935,046	960,087
10% Discount Factor	(1,053,502)	(530,812)
Standardized Measure of Discounted Future Net Cash Flows	881,544	429,275	$ 372,139	$ 1,090,660
Assets Held for Sale
Future Costs:
Standardized Measure of Discounted Future Net Cash Flows	$ 109,134	$ 77,146

Oil and Gas Reserves Information (Unaudited) - Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Extractive Industries [Abstract]
Percentage of discount factor	10.00%	10.00%

Oil and Gas Reserves Information (Unaudited) - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017 $ / bbl $ / Mcf	Dec. 31, 2016 $ / bbl $ / Mcf
Crude Oil and NGL Per Barrel
Average Sales Price And Production Costs Per Unit Of Production [Line Items]
Average sales prices \| $ / bbl	48.71	37.62
Natural Gas Per Thousand Cubic Feet
Average Sales Price And Production Costs Per Unit Of Production [Line Items]
Average sales prices \| $ / Mcf	2.88	2.29

Oil and Gas Reserves Information (Unaudited) - Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Extractive Industries [Abstract]
Standardized Measure, Beginning of Year	$ 429,275	$ 372,139	$ 1,090,660
Net change in sales price, net of production costs	326,662	(45,379)	(751,774)
Development costs incurred during the year which were previously estimated	119,864	45,648	157,390
Revisions of quantity estimates	57,042	113,583	(111,454)
Accretion of discount	43,130	37,251	114,427
Changes in future development and abandonment costs	(62,509)	5,315	14,901
Changes in timing and other	(15,565)	(38,071)	(44,439)
Extensions and discoveries	167,135	70,149	56,216
Sales of minerals in place	(6,027)	(22,449)	(43,694)
Sales, net of production costs	(194,562)	(107,253)	(163,336)
Net changes in income taxes	17,099	(1,658)	53,242
Standardized Measure, End of Year	$ 881,544	$ 429,275	$ 372,139